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Home My WebLink About193-114MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC X-28 PRUDHOE BAY UNIT X-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 X-28 50-029-22394-00-00 193-114-0 W SPT 8539 1931140 2135 663 665 665 664 18 18 18 20 4YRTST P Bob Noble 8/14/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT X-28 Inspection Date: Tubing OA Packer Depth 32 2415 2382 2372IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814150245 BBL Pumped:3.9 BBL Returned:3.3 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:27:37 -08'00' • • /pro tq3- 11* Loepp. Victoria T (DOA) From: Wallace,Chris D (DOA) Sent: Wednesday,July 13, 2016 10:11 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU X-28(PTD 193-114)WI or WAG? Follow Up Flag: Follow up Flag Status: Flagged Victoria, I do not see any restrictions on X-28 and I see the August 2014 passing MIT. Last schematic has perforations at 10,655 ft MD and I see a top packer for the IA as 10,213 ft. Should be good for WAG. Last WAG was 2001. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542 (fax),chris.wallace@yalaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Wednesday, July 13, 2016 9:19 AM To: Wallace, Chris D (DOA) Subject: PBU X-28(PTD 193-114)WI or WAG? SC.ANNED FEB 0 82017 Chris, Could you please confirm whether this well is an approved WI or WAG? RBDMS shows the status as a WAG but all the Sundries, PTD etc show it as a WI with the exception of a sundry in 2005 where WGA crossed off WI and marked WAG. Just want to make sure it is a WAG before they inject gas. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.gov CONFIDENTIALLY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged 1 . . Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. J q 3 - I (1- File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts .- Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NolType OVERSIZED . 0 Logs of various kinds o Other COMMENTS: t.P -1 .:\~~~ \ ianna Vincent Nathan Lowell Date:4, c¡,a) Is! '~ o TO RE-SCAN Notes: Re-Scanned by: 8ever1y Dianna Vincent Nathan Lowell Date: Is! Schtumberger Alaska Data & Consulting Services 2525 Caambell Sireet, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job N °I3~~~~- - f ~ ~~ ~ Log Description Date BL NO. 5353 Company: State o( Alaska Maska Oil & Gas Cons Comm Ann: Christine Mahnken 333 West 7th Ave, Suite /00 Mchorage,AK 99501 Color CD osn vos -0 ..~ ` _ ii ~rrt_~ V-02 W-26A N-32 B2WY-00018 61JJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ' MEM PRODUCTION PROFILE - PRODUCTION PROFILE ~ L- 07/27/09 07/26/09 07/25/09 1 1 1 1 1 ~ P2-29 L247 L2-06 AYTU-00052 ANHV-00106 B69K-00007 INJECTION PROFILE ~'? -~ LDL CROSS FL W CHECK 08/02/09 08/02/09 07/31/09 1 1 1 1 1 ~ P2-28 L-213 V-221 AYTU-00051 82WY-00019 AX80.00037 INJECTION PROFILE C, -~ MEM INJECTION PROFI E' MEM INJECTION PROFILE' - 08/01/09 07/29/08 p7/pg/pg 1 1 ~ 1 1 ~ L-220 07•22 04•02A B1JJ-00035 AZCM-00036 AYS4-00091 MEM INJECTION PROFILE ~ PRODUCTION PROFILE ~ USIT ~ 07/30/09 OB/09/09 08/11/09 1 1 1 1 ~ 1 J-11A L1-09 X-28 AWLB-00029 AYS4-00089 AXBD-00026 USIT PRODU TION PROFILE _p(~ MEM INJECTION PROFILE lJ 08lOS/09 08/OB/09 05/17/09 1 1 1 1 1 1 L2-06 3-29/J-32 06-04A 835~-00020 AP3~-00055 BSJN-00009 PRODUCTION PROFILE IBP SET RECORD W/CROSSGLOW ! RST 08/14/09 08/08/09 OB/23/09 1 1 1~ 1 1 t 15-498 B2NJ-00013 MCNL - 07/15/09 1 1 03•320 09AKA0030 OHMWD/LWDEDIT 02/28/09 2 1 G-14B AWJI-00043 MCNL - 07/24/09 1 1 L2-13A AWJI-00036 MCNL - 06/17/09 ~ 18-028 AWJI-00045 MCNL $~ 08/17/09 1 ~ P1-OS AWLB-00032 RST 08/09/09 1 1 B-16A B2WY-00020 MCNL ' - - OBl03/09 1 7 J-20B AXB0.00020 MCNL (REVISED) ~- .(~ ~"~. ' 04/12/09 7 PLEASE AL'KNAWI FnC.F RF( `GIDT RV CI(_IJIU !_ nun oer~ ~ou~ur_ nu~ n.~..v ~..... ~..._ ~ BP Expbration (Alaska) Inc. Petro~echnical Dafa Center LR2-1 900 E. Benson Blvd. '9 ( ~ ' y' ' ~E ~~' n. ..w..o . .._ . . .. . . ~ ~ . ,. Alaska Data & Consulling Services 2525 Gambell Street, SuMe 400 Mchorage, AK 99503-2838 • ~ ..~~~ MEMORANDUM . . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K º1.?¡1 Ii /t{o 7 t DATE: Wednesday, January 17.2007 SlIBJECT: Mechanical Integrity Tests BP EXl'LORATION (ALASKA.) fNC X-28 PRUDHOE BA Y UNIT X-28 ,,\\'1 \C\3 FROM: John Crisp Petroleum [nspector Src: Inspector Reviewed By: P.l. Suprv"Tß2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT X-28 Insp Num: mitJCr070117073710 ReI Insp Num API Well Number 50-029-22394-00-00 Permit Number: 193-114-0 Inspector Name: John Crisp Inspection Date: 1/8/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---_.--- -.---.----.--- ..,--------~._--------.,...---~,..--~------,-~.-----,--_.._--._---'~..~-- Well X-28 Type Inj. w TVD 8538 IA ---_._------_._----~._--_._--_._-_. -----',----- P.T. j I93II40_TypeTes~S~T__~est psL_--=134~_ OA In1~rval _~~!~___!,/F___P_ T Tubing Notes 410 2510 2500 2480 2470 --'---J-~-"- . 2465 ---~_.__._-_... '---'-'.---'---"--_._--~---,---.-- o o o o o o 760 760 760 760 760 760 &CANNED JAN .2 5 2007 Wednesday. January 17.2007 Page 1 of ¡ f;., 1. Operations Performed: Repair Well£&) Plu:! PerforationsD Stimulate 0 OtherD Abandon 0 Alter Casing 0 Pull TubingŒ Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD , 193-1140 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO Service[&] 50-029-22394-00-00 7. KB Elevation (ft): 9. Well Name and Number: 67.88 X-28 8. Property Designation: 10. Field/Pool(s): ADL-028313 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10905 feet true vertical 9229.0 feet Plugs (measured) Weatherford IRBP @ 10675 (07/08/2003) Effective Depth measured 10675 feet Junk (measured) Pushed FasDrill Plug 10450' (10/28/2006) true vertical 8999.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20" 91.5# H-40 35 - 110 30.0 . 110.0 1490 470 SURFACE 3456 10-3/4" 45.5# L·80 34 - 3490 29.0 . 3186.0 5210 2480 PRODUCTION 10523 7·5/8" 29.7# L-80 33 . 10556 27.0 8881.0 6890 4790 LINER 503 5-1/2" 17# NT-80 10402 . 10905 8727.0 - 9229.0 7740 6280 Perforation depth: Measured depth: 10655-10671 True vertical depth: 8980-8995 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 31 " - 10406 Packers & SSSV (type & measured depth): 7-5/8" Baker S-3 Packer @ 10213 7-5/8" TIW HBBP Packer @ 10345 4-1/2" HES X Nipple @ 2040 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO completed --- cut 7-5/8", cemented NEW Tie-back 7-5/8" PROD STRG, cut & replaced part of TBG with 4-1/2" L-80 TBG. 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: --- --- 0 0 0 Subsequent to operation: ... --- 0 0 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ} Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ K OilD GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 306-305 Printed Name DeWayne R. Schnorr II Title Petroleum Engineer Signature A::- ~ Æ ,LV ./ Phone 564-5174 Date 11/7/06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIDN/S'¡ i~ . RECEIVED , . \) 8 ¿ RBDMS SH '~.' ¡\, 20n6' t\;¡; ,Ii Form 10-404 Revised 4/2004 TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4" 5M CIW 11" 5M FMC BAKER 68' 41' 1519' 44 @ 6314' 10543' 8800' SS X-28 FROM DRLG - DRAFT 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 10247' I TOP OF 5-1/2" LNR I 14-1/2" TBG, 12,6#, L-80, ,0152 bpf, I) = 3.958" I 10406' 10402' 7-5/8" CSG, 29.7#, 10 = 6.875" I PERFORA TION SUt.fv1ARY REF LOG: BHCA ON 12/02/93 A NGLE AT TOP PERF: 3 @ 10557' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 3-3/8" 6 10557 - 10575 S 05/15/00 3-3/8" 6 10648 - 10655 S 05/15/00 3-3/8" 6 10655 - 10671 C 05/19/00 3-3/8" 6 10680 - 10706 S 05/15/00 5-112" LNR, 17#, NT-80, .0232 bpf, I) = 4.892" I 10905' I mID I 10823' DA TE REV BY COMMENTS 12/06/93 MRL ORIGINAL COMPLETION 06/20/03 BMcNlTL IBP FISH 07/08/03 PWE/TLP FISH IRBP. SETWFD IRBP 08/20/04 LDKlTLP SET IBP 04/26/06 DPS/PJC OA OWN SQUEEZE 05/02/06 SB/PJC OA OWN saz CORRECTION OA TE REV BY COMMENTS 10/31/06 D14/PAG ORLG DRAFT CORRECTIONS 2040' 10192' 10213' 10237' 10309' 10326' 10345' 10375' 10393' -14-1/2" HES X NIP, 10 = 3.813" 4-112" HES X NIP, 10 = 3.813" 7-5/8" X 4-1/2" BKR S-3 PKR 4-112" HES X NIP, 10 = 3.813" UNIQUE MACHINE OVERSHOT 4-112" PARKER SWS NIP, I) = 3.813" 7-5/8" X 4-112" TIW HBBP PKR, ID = 4.0" 4-1/2" PARKER SWS NIP, I) = 3.813" 4-112" PA RKER SWN NIP, I) = 3.725" 10406' 4-1/2" WLEG, 10 = 3.958" 10396' H ELMOTTLOGGED04/10/94 1 10675' SET WEA THERFORD IRBP 07/08/03 PRUDHOE BAY UNIT WELL: X-28 PERMIT No: '1931140 API No: 50-029-22394-00 SEe 7, T10N, R14E, 4887' FSL & 84' FEL BP Exploration (Alaska) . . X-28 DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 07/03/2006 T/lA/OA=150010/225 Eva!. T X IC comm. PPPOT-T-IC PPPOT-T 5,000 Passed PPPOT- IC Passed Sting into 7-5/8" IC test void to monitor pressure [0] on void pressure up on test void to 3,800 for 30 minutes.LDS did not require any torque to test. Sting into test void on tubing hanger, got back small amount of old test fluid, test void to 5,000 for 30 minutes. LOS did not require any torque to test. AWGRS 07/07/2006 T/l/O=150/20/250 MIT-OA TO 2500 FAILED Pumped 4 bbls crude to reach test pressure OA lost 1560 psi in first 15 min on test 1 and lost 1500 psi in first 15 min on test 2 could not establish LLR at 2500 psi took 1 .5 bbls to keep pressure at 2500 psi for a 112 hr FWHP=250/20/300 AWGRS 07/28/2006 ***WELL S/I ON ARRIVAL*** (RWO Screening) ARRIVE ON LOCATION, INSPECT AREA, BEGIN R!U TO CALIPER TBG. AWGRS 07/29/2006 DRIFT TUBING WITH 3.50" G-RING, UNABLE TO PASS 3364' SLM , DRIFT TUBING W/2 1/8" STEM, 3.50" CENT. & SAMPLE BAILER TO 10529' SLM, TIGHT BETWEEN 3364'-3470' SLM CALIPER TUBING FROM 10450' SLM, PDS CALIPER! 3.375" CENT. (GOOD DATA) ***WELL LEFT SII, DSO NOTIFIED*** AWGRS 08/23/2006 T/l/O=40010/200 PPPOT-T (passed) Void @ 0 psi. Tested @ 5000 psi with no pressure loss after 30 min. All LOS functioned & torqued @ 450 ft #. PPPOT-IC (passed) 50 psi on void bled to 0 psi. Tested @ 3000 psi with no pressure loss after 30 min. All LOS functioned & torqued @ 450 ft #. AWGRS 09/09/2006 ** WELL SHUT IN UPON ARRIVAL** (RWO prep/pulllBP) RIG UP SIL UNIT. AWGRS 09/10/2006 (RWO Prep) DRIFTED TBG WITH 3.625" SWAGE UP TO A 3.75" GAUGE RING, WORKED TIGHT AREA FROM 3320' SLM TO 3470' SLM. APPEARS TO BE SCHMOO BIULD UP IS THE SOURCE OF THE RESTRICTION. LATCHED IBP @ 10536' SLM, VERY POOR JAR ACTION, DRUG IBP TO 3700' & SHEARED PULLING TOOL, IBP FELL BACK TO BOTTOM. LATCH IBP WI 41/2" BAIT SUB WI OVERSHOT @ 10,654' SLM, PULLING VERY HEAVY. AWGRS 09/11/2006 PULLED IBP FROM 10654' SLM, RUBBER WAS PEELED UPSIDE DOWN BUT ALL INTACT. DRIFT WI 3.70" CENT. SIT DOWN @ 10,663' SLM (NO OBSTRUCTIONS) SAMPLE BAILER FULL OF SCHMOO ***WELL LEFT SI*** AWGRS 09/21/2006 T/I/O=140NAC/120, Temp=SI. Monitor WHP's, TBG & IA FL's (E-line). TBG FL @ 1356' (21 bbls), IA FL @ 48' (1 bbl). AWGRS 09/23/2006 TIIIO = 135Nac/0 CMIT TxlA to 2000 psi PASSED (Assist E-Line) Pumped 28.6 bbls of crude down tubing to reach test pressure. Tubing lost 40 psi in the 1 st 15 min and 40 psi in the 2nd 15 min. IA lost 20 psi in the 1 st 15 min and 0 psi in the 2nd 15 min. Total losses in the 30 min test. Tubing = 80 psi. IA = 20 psi. Bleed TxlA back down. Final WHP's = 0/0/150 Page 1 . . X-28 DESCRIPTION OF WORK COMPLETED AWGRS 09/23/2006 WELL SHUT IN ON ARRIVAL. SSV WAS OPEN. INITIAL TIIIO = 20010/200 RAN 4.5" HALIBURTON FAS DRILL PLUG WITH MAX OD=3.66". SET PLUG @ 10361' RAN 1 11/16" TUBING PUNCHER LOADED 4 SPF. SHOOTING INTERVAL 10230' - 10232' TIIIO BEFOR TBG. PUNCH = 010/200. NO CHANGE. POOH WITH TBG PUNCH TO RIG UP STRING SHOT (PRE-CHEM CUT). AWGRS 09/24/2006 *** WELL SI ON ARRIVAL *** (fish) ATTEMPTING TO FISH E-LlNE BULLNOSE OFF STRING SHOT WI MAGNETS & FINGER BASKET FROM TOP OF FASDRILL PLUG @ 10,351' SLM...RAN 3.50 LIB TO 10,351' SLM, L T MARK ON EDGE OF BLOCK, POSSIBLY TOP OF FISH *** JOB IN PROGRESS *** AWGRS 09/24/2006 SHOT 2 STRAND X 17' STRINGSHOT AT 10274' -10291' BOTTOM NOSE ON STRINGSHOT LEFT DOWNHOLE FINAL TIIIO = 5010/200 ** Job not complete: rigged down for SL to fish bottom nose.** PAD NOTIFIED UPON DEPARTURE. AWGRS 09/25/2006 WELL SHUT IN ON ARRIVAL. SSV OPEN. FUSIBLE CAP INSTALLED THAT WAS REMOVED WITH PAD OPERATORS PERMISSION. INITIAL- T/I/O= 500/300/200 CHEMICAL CUT THE TUBING WITH 35/8" CHEMICAL CUTTER AT 10286' IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE PACKER. MAX LENGTH=28.7'. MAX OD=3.625". WELL SHUT IN ON DEPARTURE. SSV OPEN AND CONTROL TURNED BACK OVER TO PAD OPERATOR. FUSIBLE CAP NOT RE-INSTALLED. PAD OPERATOR NOTIFIED. *****JOB COMPLETE***** AWGRS 09/25/2006 (fish e-line tools) MADE SEVERAL ATTEMPTS TO FISH BULLNOSE OFF BOTTOM OF E-LlNE STRING SHOT. RDMO ***JOB INCOMPLETE, E-LlNE FISH STILL IN HOLE *** AWGRS 09/26/2006 TIIIO= 40010/200 - Circ Out (Pre-RWO) - Pumped 5 bbls neat meth followed by 694 bbls seawater down TBG taking returns up IA through Cosasco loop to X-22 flowline. AWGRS 09/26/2006 T/I/O=120NAC/20, Temp=SI. Monitor WHP's (pre-rig). AWGRS 09/27/2006 Circ out, CMIT TxlA 2000 psi ***PASSED*** (Pre RWO) - Pumped 51 bbls 70* seawater down TBG taking returns up IA through Cosasco loop to X-22 flowline. Pressured up TxlA to 2000 psi w/3.1 bbls 45* 60/40 meth water. (1st test) TBG lost 20 psi in 1st 15 min and 30 psi in 2nd 15 min. IA lost 10 psi in 1st 15 min and 40 psi in 2nd 15 min. TBG lost a total of 50 psi and IA lost a total of 50 psi in 30 min test. (2nd test) - TBG lost 10 psi in 1st 15 min and 10 psi in 2nd 15 min. IA lost 0 psi in 1st 15 min and 20 psi in 2nd 15 min. TBG lost a total of 20 psi and IA lost a total of 20 psi in 30 min test. Bled press. Freeze protect IA w/1 05 bbls 60/40 meth water taking returns up TBG to X-22 flowline. Freeze protect TBG w/38 bbls 60/40 meth water taking returns up IA to X-22 flowline. FWP's=OIOIO Freeze protect X-22 flowline w/7 bbls meth and 87 bbls crude per WOA procedure. AWGRS 10/16/2006 T/I/O=OIOIO Assist Doyon 14 with LLR down OA While rig circulated TBG x IA. - Pump SW down OA to attempt LLR, OA presured up to 2500 psi wI 1.3 bbls away, Monitor WHP's & repressure OA to 2500 psi 3 times wI an additional 1.1 bbls SW over 25 minute time span RD. DIMS 10/16/2006 Move rig, RU, Pull TWC, RU cir lines, Pump freeze protect out to tiger tank, Perform OA injection test, Set & test TWC, ND tree. Page 2 . . X-28 DESCRIPTION OF WORK COMPLETED AWGRS 10/16/2006 PULLED BPV I RIG MOVED ON WELL. DIMS 10/17/2006 DIMS 10/18/2006 DIMS 10/19/2006 DIMS 10/20/2006 DIMS 1 0/21/2006 DIMS DIMS DIMS DIMS DIMS DIMS NU BOPE, Test BOPE, Pull TWC, Engage hanger, Cir well clean (tbg not free), RU SWS, Run free point log (free @ 10310'). Run free point, Run string shot, Run chem cutter, RD SWS, Pull hanger to floor, Cir hole clean, UD 41/2" tbg, Attempt to test csg, Install wear ring. M/U dress off BHA, RIH, Dress stub, Rev cir, Test csg (failed), POH, MU RBP, RIH. Cont RIH, Set RBP, Test RPB, POH, RU SWS, RUN USIT logs, Run string shot,RD SWS, RIH w/RBP. Cont RIH w/RBP, Set & test RBP, Dump sand, Slip & cut drlg line, POH, MU MS cutter, RIH, Cut csg, Cir OA clean, POH, LD BHA, C/O rams, Test rams, C/O leaking kill HCR valve. 10/22/2006 C/O HCR valve & test, Engage csg wlspear, BOLDS, Pull hanger to floor, Cir hole clean, UD 7 5/8" csg, C/O rams & test, RIH w/10 3/4"scraper, Displace to 9.8 brine, POH, M/U washover BHA. 10/23/2006 RIH, Washover stub, Rev cir, POH, M/U backout BHA, RIH, Backout stub, POH, M/U spear BHA, RIH, Engage stub, POH wlstub, UD stub, C/O top rams & test, R/U for 7 5/8" csg, M/U ES cementer, baffle, triple connection bushing wlcollar, and o-shot guide shoe. 10/24/2006 PJSM - Run 75/8" casing to 2744' - Screw into casing stub wI TCB - Circ - Cement- Disp. - ND - Install I Set emergency slips - Cut csg wI Wachs cutter - Install packoff /Tubing spool I RILDS - Attempt t/ test packoff - Pull pack off I Inspect. 10/25/2006 Install Pack-off - Test to 3500 psi - NU Stack - Test BOP's - Mob Clean out assy. 10/26/2006 MU cln out assy. - RIH - Drill cmt/shoe trk - Wash to 3724' - Circ sweep - Press test csg - POH - Test csg - BHA - RIH - Wash to 3790' - Disp - POH - Cln bskts - BHA - RIH - Drill junk - POH - Cln bskts - MU RBP ret. tool - RIH. 10/27/2006 RIH - Latch RBP - POH - Test casg - MU Retrieving tool- RIH w/BHA - Cut drilling line- RIH @ 6533' Test casg to 4000 - RIH - CBU - Test casg to 4000 - RIH - Latch RBP- CBU - POH - LD RBP - DIMS 10/28/2006 DIMS 1 0/29/2006 DIMS 1 0/30/2006 MU BHA - RIH - Drill Fasdrill plug I push to 10,450' - CBU - POH I LD DP - BHA - RU Tbg tools - Run 41/2" Tbg completion. Run 41/2" Completion - Land - Freeze protect - Set Packer - Test tubing to 4000. Test IA - Install TWC - Test - ND BOP's - NU adapter test to 500010 mins - NU Tree test to 5000 15 mins RU lubricator - Pull TWC ~ Install BPV - RD Lubricator ~ Secure well. AWGRS 10/30/2006 PULLED TWC IRIG TESTED THE TREE I BPV WAS SET FOR THE RIG TO MOVE OFF. Page 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 1 0/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/16/2006 05:00 - 07:30 2.50 MOB P PRE PJSM - Move rig from maintenance area to X-28 07:30 - 09:00 1.50 MOB P PRE Shim rig - PJSM - Skid rig floor 09:00 - 12:00 3.00 MOB P PRE Oemobilize summer maintenance - Clear all tools, equipment, and oily waste from pipe shed - Install all covers and landings on skate - Clear all tools, equipment, and waste from rig floor - Rig up mud, choke, and kill lines - Rig up water, steam, air, and top drive - Recondition #4 valve on choke manifold- (Accept rig @ 1200 hours) 12:00 - 13:00 1.00 RIGU P PRE Inspect derrick and cellar 13:00 - 14:00 1.00 DHB P DECOMP RlU OSM lubricator - Pull TWC 14:00 - 16:30 2.50 CLEAN P DECOMP RlU double valve and lines to displace meth/water freeze protect to tiger tank - Test lines with air - RlU flange on OA for Hot Oil 16:30 - 17:00 0.50 CLEAN P DECOMP PJSM - Pump 40 bbls seawater down annulus taking returns from tubing to tiger tank (650 psi @ 40 SPM) 17:00 - 18:00 1.00 CLEAN P DECOMP Blow down lines - Swap hoses - Pump 140 bbls seawater down tubing taking returns from annulus to tiger tank (650 psi @ 40 SPM) 18:00 - 18:30 0.50 CLEAN P DECOMP Allow meth/water to migrate - Perform OA injection test with Hot Oil ( pumped 1.3 bbl @ 1/4 BPM to 2500 psi, bled down to 2340 psi in 5 min, pumped .2 bbl @ 1/4 BPM to 2500 psi, bled down to 2000 psi in 5 min, pumped .3 bbl @ 1/4 BPM to 2500 psi, bled down to 1820 psi in 5 min, pumped .5 bbl @ 1/4 BPM to 2500 psi, bled down to 780 psi in 30 minutes, total pumped = 2.4 bbls) 18:30 - 19:00 0.50 CLEAN P DECOMP Pump 40 bbls seawater down tubing taking returns from annulus to tiger tank ( 520 psi @ 40 SPM) 19:00 - 19:30 0.50 EV AL P OECOMP Confirm well is dead - Install TWC with FMC 19:30 - 22:00 2.50 EV AL P DECOMP Test TWC from bottom to 1000 psi for 30 min - Test TWC from top to 4000 psi for 10 min 22:00 - 23:30 1.50 WHSUR P DECOMP PJSM - ND tree 23:30 - 00:00 0.50 WHSUR P DECOMP Cap SSV lines - Inspect and confirm threads in tubing hanger with XO (7.25 turns) 10/17/2006 00:00 - 02:30 2.50 BOPSU DECOMP Install 3' spacer spool- N/U BOP, choke line, riser, and flow line 02:30 - 03:30 1.00 EVAL DECOMP Clear floor - RlU test equipment 03:30 - 10:30 7.00 BOPSU DECOMP Test BOPE - Test performed w/4" test joint - Annular, 3 1/2" X 6" top VBR's, choke manifold, HCR choke/kill, manual choke/kill, floor safety valves, upper/lower IBOP, 27/8" X 5" lower VBR's, blind rams tested to 250 psi low / 4000 psi high for 5 minutes each - Performed accumulator test - Pull 4" test joint - Install 4 1/2" test joint - Test top 31/2" X 6" VBR's to 250 psi low / 4000 psi high for 5 minutes each - All test witnessed by WSL - John Crisp with AOGCC waived witness of test 10:30 - 11 :00 0.50 EVAL P OECOMP RIO test equipment - Clear floor - Blow down choke and kill lines 11 :00 - 12:00 1.00 EVAL P DECOMP RlU DSM lubricator - Pull TWC 12:00 - 12:30 0.50 EVAL P DECOMP RID DSM lubricator - Mobilize spear BHA 12:30 - 13:00 0.50 FISH P OECOMP M/U spear asembly 13:00 - 14:00 1.00 FISH P DECOMP Engage hanger - Back out lockdown screws 14:00 - 17:30 3.50 FISH P DECOMP P/U to 280 K - Tubing not free - Pump 40 bbls safe surf pill, 50 bbls seawater, 40 bbls safe surf pill and circulate well clean @ 3000 psi / 80 SPM while working pipe from 125K to 275 K Printed: 11/612006 8:02:21 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 10/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/17/2006 17:30 - 18:00 0.50 FISH P DECOMP UD spear assembly - Mobilize 41/2" landing joint and elevators 18:00 - 19:30 1.50 EVAL P DECOMP Spot SWS - Calibrate E-line tools 19:30 - 21 :00 1.50 EVAL P DECOMP PJSM with SWS - RlU to run wireline logs 21 :00 - 00:00 3.00 EVAL P DECOMP RIH with free point indicator - Check tool @ 2500',8500', 10200', and 10310' - Pipe free @ 10310' - POOH w/wireline 10/18/2006 00:00 - 00:30 0.50 EVAL P OECOMP UD free point tools - PJSM - P/U string shot 00:30 - 02:30 2.00 EVAL P DECOMP RIH with 2 strand string shot - Fire @ 10290' /10302' - POOH w/ wireline 02:30 - 03:30 . 1.00 EVAL P OECOMP UO string shot assembly - PJSM - P/U chemical cutter 03:30 - 05:30 2.00 EVAL P DECOMP RIH with chemical cutter - Spot at 10,301' - Pull 20k over string weight - Fire chem. cutter (good indication) - Pull on pipe to ensure free (162k up wt.). 05:30 - 07:00 1.50 EVAL P DECOMP POH w/ C.C. to 200' - PJSM - LD cutter assembly 07:00 - 07:30 0.50 EVAL P DECOMP RD E-line equip. - Clear floor 07:30 - 08:30 1.00 PULL P OECOMP Pull hanger to rig floor w/162k up wt. - LO landing jt & hanger - RU to circulate 08:30 - 09:30 1.00 PULL P DECOMP Break circulation - Pump 35 bbl "Safe Surf 0" pilll - 50 bbl seawater - 35 bbl "Safe Surf 0" - Circulate around w/12 bpm 1350 psi 09:30 - 10:30 1.00 PULL P OECOMP RO circ. head - Blow down lines - change bales & elevators - RU tubing tongs 10:30 - 21 :00 10.50 PULL P DECOMP UO 4 1/2" 12.6# L-80 NSCT tubing - ( total = 254 jts, 1 cut jt @ 24.82, 2 pup jts @ 9.85 each, 55 LaSalle clamps, 2 SS band, 1 SSSV & 6 GLM's) 21 :00 - 22:00 1.00 PULL P DECOMP UO tubing equipment and clear floor 22:00 - 23:00 1.00 EVAL P DECOMP RlU and test 7 5/8" casing to 3500 psi - (failed - 15 minutes bled down from 3500 psi to 1300 psi) 23:00 - 23:30 0.50 BOPSU P DECOMP Install wear ring 23:30 - 00:00 0.50 FISH P DECOMP Mobilize dress off & scraper BHA to floor 10/19/2006 00:00 - 00:30 0.50 FISH P OECOMP Mobilize BHA #2 to rig floor 00:30 - 02:30 2.00 FISH P DECOMP MU dress off BHA & DC's to 414' 02:30 - 13:00 10.50 FISH P DECOMP PU 4" OP from pipe shed to 10,269' 13:00 - 14:00 1.00 FISH P OECOMP Break circ. - Obtain parameters - Tag top of 4 1/2" stub at 10,304' - Rotate over stub & tag w/ dress off mill - Rotate w/ 80 rpm 2-3k wt - Dress top & ID of tubing 1/ 5 min. 14:00 - 15:00 1.00 FISH P OECOMP PU 2' - Reverse circulate BU w/ 6.5 bpm 1790 psi 15:00 - 16:00 1.00 FISH P OECOMP LD 1 joint - RU & test 7 5/8" casing to 2000 psi (Bled off 350 psi in 10 min.) - Bleed off pressure - Reconfigure valves for isolation - Test to 2000 psi (Bled off 600 psi in 15 min) - Bleed off pressure 16:00 - 16:30 0.50 FISH P OECOMP RD test equip. - Blow down lines 16:30 - 20:00 3.50 FISH P DECOMP POH 20:00 - 21 :00 1.00 FISH P DECOMP Stand back DC's - UO junk baskets and dress off tools 21 :00 - 21 :30 0.50 FISH P DECOMP Clear floor - Mobilize HES RBP 21 :30 - 22:00 0.50 FISH P OECOMP M/U running tool, RBP, and OC's 22:00 - 00:00 2.00 FISH P DECOMP RIH from 371' to 4366' 10/20/2006 00:00 - 02:30 2.50 EV AL P OECOMP Continue RIH with RBP from 4366' to 10223' - (PU 225, SO 150) 02:30 - 03:00 0.50 EVAL P OECOMP Set RBP @ 10283' - Pull 5K over to verify set - Unlatch - Rack back 1 stand 03:00 - 03:30 0.50 EVAL P DECOMP Test 7 5/8" casing to 3500 psi for 30 minutes ( good test) 03:30 - 04:00 0.50 EVAL P DECOMP RIO test equipment - Blow down kill and test lines Printed: 11/612006 8:02:21 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 1 0/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/20/2006 04:00 - 07:00 3.00 EVAL P DECOMP POOH from 10223' to 6065' 07:00 - 07:30 0.50 EVAL P DECOMP Service top drive, crown and blocks 07:30 - 09:00 1.50 EVAL P DECOMP Repair drawworks chain oiler 09:00 - 10:00 1.00 EVAL P DECOMP Continue POOH from 6065' to 371' 10:00 - 10:30 0.50 EVAL P OECOMP Stand back collars 10:30 - 13:00 2.50 EVAL P OECOMP PJSM - Mobilize SWS equipment -Hang sheaves -MU packoff assembly - MU tools - Lower packoff assembly and test to 600 psi for 5 minutes 13:00 - 19:30 6.50 EVAL P OECOMP RIH with SWS US IT log - Log up from 10260' to surface - UD USIT log 19:30 - 22:30 3.00 EVAL P OECOMP PJSM - RU & run 3 strand string shot - Fire @ 2742' - POH - RlOSWS 22:30 - 23:00 0.50 EVAL P DECOMP PJSM - Clear rig floor - PU & MU HES RSP 23:00 - 00:00 1.00 EVAL P OECOMP RIH with RSP to 769' 10/21/2006 00:00 - 01 :30 1.50 EVAL P OECOMP RIH w/RSP to 3800' 01 :30 - 02:00 0.50 EVAL P DECOMP Set RSP - Verify set w/5K over pull - Unlatch - Rack back 1 stand 02:00 - 02:30 0.50 EVAL P DECOMP RlU test equipment - Test RSP to 1000 psi for 10 minutes on chart - RID test equipment 02:30 - 04:00 1.50 EVAL P DECOMP Rack back 1 stand - Dump 1500 Ibs 20/40 sand down drill pipe 04:00 - 04:30 0.50 EVAL P OECOMP Pump 1/2 DP volume (15 bbls) - Rack 1 stand back - Pump 15 bbls (30 SPM @ 40 psi) 04:30 - 06:30 2.00 EVAL P OECOMP PJSM - Cut and slip drill line - Service TD, crown, and blocks 06:30 - 08:30 2.00 EVAL P OECOMP RIH 2 stands and tag sand @ 3740' - POOH - UD RSP running tool 08:30 - 09:00 0.50 EVAL P OECOMP Clear floor - Mobilize MS cutter assembly 09:00 - 09:30 0.50 FISH P OECOMP M/U 5 1/2" Multi-string cutter assembly and 4 3/4" DC's 09:30 - 10:30 1.00 FISH P DECOMP RIH to 2658' (PU 95, SO 95, RW 93, 50 RPM, TO 1, 34 SPM @ 250 psi) 10:30 - 11 :30 1.00 FISH P DECOMP Locate collar @ 2743' - PU and cut casing @ 2723' (50 SPM, 800 psi, 60 RPM, TO 3 ) 11 :30 - 12:00 0.50 FISH P DECOMP RlU hardline to OA and test line with air 12:00 - 13:00 1.00 FISH P OECOMP Wait on Hot Oil 13:00 - 17:30 4.50 FISH P DECOMP PJSM - RU Hot Oil - Test lines - Close annular taking returns out OA - Pump 35 bbls soap pill - Pump 110 bbls 190 degree diesel 1.5 SPM @ 450 psi - Pump 40 bbls soap pill - Allow to soak for 30 minutes - Pump 50 bbls hot diesel - Oisplace with 300 bbls hot seawater @ 220 gpm 1150 psi 17:30 - 18:30 1.00 FISH P DECOMP Open annular - Circulate IA clean - Flow check - Slowdown lines 18:30 - 19:30 1.00 FISH P DECOMP POOH from 2723' to 374' 19:30 - 20:30 1.00 FISH P OECOMP Stand back collars - Make service breaks - UD MS cutter - Clear floor 20:30 - 22:00 1.50 FISH P DECOMP PJSM - Pull wear ring - Install test plug with 7 5/8" test joint - Change out upper rams to 7 5/8" 22:00 - 23:00 1.00 FISH P DECOMP Test rams to 250 psi low, 3500 psi high for 5 minutes on chart (good) - Kill HCR valve failed with exterior leak 23:00 - 00:00 1.00 FISH P DECOMP Change out kill HCR valve 10/22/2006 00:00 - 02:30 2.50 FISH N RREP OECOMP Continue change out kill HCR valve - Test kill HCR valve to 250 psi low, 3500 psi high for 5 minutes on chart 02:30 - 03:00 0.50 FISH P OECOMP RIO test equipment - Mobilize spear assembly 03:00 - 04:00 1.00 FISH P DECOMP MIU spear - RIH - Engage 7 5/8" casing 04:00 - 04:30 0.50 FISH P OECOMP Sack out lock down screws - Pull hanger free w/150k - Pull to Printed: 11/612006 8:02:21 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 10/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/22/2006 04:00 - 04:30 0.50 FISH P DECOMP rig floor wI 130k up wt. 04:30 - 05:00 0.50 CASE P OECOMP Circulate surface to surface wI 8.5 bpm 1030 psi 05:00 - 06:00 1.00 CASE P DECOMP Release spear - LD same - RU casing equip. - LD hanger 06:00 - 09:30 3.50 CASE P DECOMP PJSM - LD 7 5/8" 29.7# NSCC casing - Recovered 67 jts + cut jt(18.80') 09:30 - 11 :00 1.50 CASE P OECOMP Clean up rig floor - RO casing equip. - Clear rig floor 11 :00 - 12:30 1.50 CLEAN P DECOMP PJSM - Install test plug - Change top rams to 31/2" x 6" variables 12:30 - 13:00 0.50 CLEAN P DECOMP Test rams to 250 low 3500 high - RD test equip. 13:00 - 13:30 0.50 CLEAN P OECOMP Lubricate rig 13:30 - 14:00 0.50 BOPSU P OECOMP Install wear bushing 14:00 - 16:00 2.00 CLEAN P OECOMP PJSM - M/U 10 3/4" scraper BHA 16:00 - 17:00 1.00 CLEAN P DECOMP RIH from 399' to 2720' 17:00 - 17:30 0.50 CLEAN P DECOMP Tag stump @ 2723' - Continue RIH - Tag scraper on stump @ 2723' (PU 98, SO 95) 17:30 - 18:30 1.00 CLEAN P DECOMP Displace well with 9.8 ppg brine (300 gpm @ 630 psi) - Flow check 18:30 - 19:30 1.00 CLEAN P OECOMP POOH from 3090' to 399' 19:30 - 20:30 1.00 CLEAN P DECOMP UD jars, scraper and stand back OC's - UO bit 20:30 - 21 :00 0.50 CLEAN P OECOMP Clear floor - Mobilize washover BHA to floor 21 :00 - 23:00 2.00 CLEAN P OECOMP Service break spear - M/U washover BHA 23:00 - 00:00 1.00 CLEAN P OECOMP RIH from 429' to 1810' 10/23/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue RIH from 1810' to 2713' (PU 92, SO 90,126 gpm @ 310 psi) 01 :30 - 02:00 0.50 CLEAN P DECOMP Wash over stub from 2723' to 2751 ' 02:00 - 03:00 1.00 CLEAN P OECOMP Reverse circulate well clean @ 2723' (252 gpm @ 580 psi) 03:00 - 04:00 1.00 CLEAN P OECOMP POOH to BHA at 429' 04:00 - 06:00 2.00 CLEAN P DECOMP Stand back DC's - LO wash over assembly 06:00 - 06:30 0.50 FISH P OECOMP Clear floor - Mobilize BHA to rig floor 06:30 - 07:30 1.00 FISH P OECOMP RIH wI DC's to 366' - PU backoff BHA 07:30 - 11 :30 4.00 FISH P DECOMP RIH fl 399' to 2723' - Tag top of stub - Enter 75/8" casing wI OC's - RIH to 3185' BHA depth - Fill pipe - PU & spot power section across collar at 2743' 11 :30 - 12:30 1.00 FISH P OECOMP Pressure to 1000 psi & set btm anchor - Set down 15k on same - Bleed off - pressure to 3000 psi to ensure top anchor set - Set 35k down on top anchor - Bleed pressure - Pressure to 1600 psi (10,500 ftIlbs) to break 7 5/8" casing connection- Bleed off to cycle tool - Repeat process until 5 full turns were achieved - PU on string to release anchors - Drop dart - Open pump out sub - Pump pipe volume 12:30 - 13:30 1.00 FISH P DECOMP Flow check - POOH from 2723' to 399' 13:30 - 14:30 1.00 FISH P DECOMP UD back out BHA - Make service breaks - Stand back DC's 14:30 - 15:00 0.50 FISH P DECOMP M/U spear BHA assembly 15:00 - 15:30 0.50 FISH P DECOMP RIH to 2723' 15:30 - 16:00 0.50 FISH P OECOMP Engage and backout stub - Flow check 16:00 - 17:00 1.00 FISH P OECOMP POOH from 2723' to surface wlfish 17:00 - 18:00 1.00 FISH P DECOMP UD fish - Service break and UO spear (Casing collar came out with fish - cut joint = 21.16) 18:00 - 18:30 0.50 BOPSU P OECOMP Clear floor - Pull wear bushing - Install test plug 18:30 - 20:00 1.50 BOPSU P DECOMP CIO top rams to 7 518" 20:00 - 20:30 0.50 BOPSU P DECOMP RlU tst equipment - Test top rams to 250 psi low, 3500 psi high for 5 minutes each on chart - RIO test equipment 20:30 - 23:00 2.50 CASE P OECOMP RlU to run 7 5/8" TC-II casing Printed: 11/612006 8:02:21 AM ,¡ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 10/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/23/2006 23:00 - 00:00 1.00 CASE P OECOMP M/U collar, guide shoe, ES cementer, and XO joint 10/24/2006 00:00 - 01 :00 1.00 CASE P DECOMP Continue RU casing equip. - MU Triple Connection Bushing - Es cementer - XO joint 01 :00 - 07:00 6.00 CASE P DECOMP Run 66 jts 7 5/8" 29.7# TCII casing using torque turn services - Tag top of 7 5/8" stub at 2744' - NOTE: Rejected 2 joints (#'s 63 & 66) 07:00 - 08:30 1.50 CASE P DECOMP MU 14' TCII Pup jt - TCII x 4 1/2" IF - 4 1/2" x HT38 XOs - Screw into casing wI TCB - Torque to 7K - Pull 250k and work torque down repeatedly to achieve 7k torque down hole 08:30 - 09:30 1.00 CASE P DECOMP RD casing equipment - CO short bails - Elevators - Clear rig floor - MU cement head - XOs 09:30 - 10:30 1.00 CASE P DECOMP RU test equipment - Pull 250k on casing - Pressure test to 2000 psi (bled down 100 psi over 10 min. on chart) Bleed off pressure to remove trapped air - Pressure up to 2000 psi f/15 minutes - Record on chart (good) Bleed off pressure - RD test equip. - Pressure up on casing to 3200 psi to open HES Cementer. 10:30 - 11 :30 1.00 CASE P DECOMP CBU at 6.5 BPM I PP 180 - PJSM wI SLB cementers and rig crew 11 :30 - 13:30 2.00 REMCM P DECOMP Pump 5 bbls water ahead I BPM 3 I PP 90 Test cement lines to 4000 psi Pump 130 bbls I 620 sx Class "G" cement wI Gasblok I 2 ppb "Cemnet" @ 15.8 ppg I BPM 5 I PP 100 Kick out closing plug wI 5 bbls water Displace cement wI 121 bbls 9.8 ppg Nacl brine I BPM 8 I PP 600 Slowed pump to BPM 2.51 PP 960 (cement retums observed at surface @ 960 stks) Bumped plug wI 1180 stks (estimated cement returns to surface 21 bbls) Increased pump pressure to 2000 psi to close HES cementer- Bled off pressure - Check ES cementer - No returns - CIP @ 12:50 hrs. 13:30 - 15:00 1.50 CASE P OECOMP Flush cement from stack wI treated water - RD cement head - PJSM - Blow down lines - Orop riser - ND stack I choke hose I Riser - Lift stack 15:00 - 18:00 3.00 CASE P OECOMP Pull 400k wI rig - Install emergency slips - Set slips wI 350k on casing - Cut casing wI Wachs cutter - LD cut jt. 39.51' 18:00 - 00:00 6.00 CASE P DECOMP PJSM - Remove tubing spool - Attempt to install pack off (unsuccessful) Pull pack off - File and prep casing stub - Install pack off - Install new tubing spool - RILOS - Attempt to test seals to 500 psi (bled off) No fluid observed 10/25/2006 00:00 - 01 :30 1.50 WHSUR P DECOMP Pull 103/4" x 75/8" packoff (leaking by lower seals) - W.O. new packoff 01 :30 - 06:30 5.00 WHSUR P DECOMP Attempt to install new packoff through tubing spool - Would not seat - Pull packoff - Inspect seals (good) - ND Tubing spool - Set Pack-off - NU Tubing spool - Attempt to test - No Test leaking by lower seals - (Fluid observed through OA valve) - Pull Pack-off - ND Tubing spool - Packed plastic in void area on top of slips - Set pack-off - NU Tubing spool - Attempt to test - Pressure up to 1100 psi - Pressure dropped to 100 psi - Observed fluid leaking passed lower seals - (Fluid observed through OA valve) Printed: 11/6/2006 8:02:21 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 10/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: W.O. plastic pump from Tool Service - RU pump - Pump plastic into packoff void - Pump through both ports with plastic to 3500 psi - Shut in isolate ports with gauges - Set Stack on tubing spool 14:00 - 15:00 1.00 OECOMP Install test plug - Change rams from 7 5/8" Casing rams to 3 1/2" x 6" VBR's - Pull test plug 15:00 - 17:30 OECOMP PJSM - NU Stack - NU Choke - Riser I Flowline 17:30 - 18:30 DECOMP Flush stack with stack washer - Work rams - Flush choke I kill lines - Blow down 18:30 - 19:30 DECOMP Install Test plug - RU testing equipment 19:30 - 23:30 DECOMP Test BOP's - Annular 250 low 3500 high - 5 mins each test - Top VBR 3 1/2" X 6" - Choke manifold - HCR Choke I Kill - Manual Choke I Kill valves - Floor Safety valves - Bottom VBR 27/8" X 5" rams - 250 low 4000 high 5 mins each test - Preform Accumulator test - Test Blind rams 250 low 4000 high 5 mins each test - Change out 4" test joint to 4 1/2" test joint - Test Top VBR's to 250 low 4000 high 5 mins each test - All test were witnessed by WSL - Chuck Scheve with AOGCC waived witness of BOP test 23:30 - 00:00 0.50 BOPSU P OECOMP RO testing equipment - Blow down - Install wear bushing - Hydraulic oil leaking on tubing spool I well head flange 10/26/2006 00:00 - 01 :00 1.00 CASE P OECOMP Moblize BHA to floor - MU BHA 6 3/4" clean out assy 01:00 - 01 :30 0.50 CASE P DECOMP Bleed off pressure on Tubing spool I Well head flange - Tighten up flange bolts - Pressure up to 3700 psi with FMC plastic pump - Hold for 30 mins pressure steady (Visually monitor "OA" - no leak observed) 01 :30 - 02:00 0.50 CASE P OECOMP RIH with 4 3/4" DC's 02:00 - 03:00 1.00 CASE P DECOMP RIH from 395' to 2679' - Break Circulation - Tag cement @ 2689' 03:00 - 04:00 1.00 CLEAN P OECOMP Orill cement from 2689' to 2729' 04:00 - 05:00 1.00 CLEAN P DECOMP Orill ES-Cementer - WOB 10k - 2k Tq 05:00 - 06:00 1.00 CLEAN P DECOMP Pump H.V. sweep - Orill out baffle adapter. 06:00 - 06:30 0.50 CLEAN P DECOMP RIH to 3740' - Tag sand - Hit down lightly & dry drill to break up larger pieces 06:30 - 07:00 0.50 CLEAN P DECOMP Pump H.V. sweep around 07:00 - 09:00 2.00 CASE P DECOMP RU & attempt to test 7 5/8" casing to 3500 psi (bleeding off) - Bleed off pressure - Close bottom rams - Repeat test. Pressure bled off 600 psi in 30 min. - 150 psi next 15 min. (Visually monitor "OA" - No leak observed) 09:00 - 09:30 0.50 CASE P OECOMP RO test equip. - Circulate to balance fluid. 09:30 - 11 :00 1.50 CASE P OECOMP POH to BHA at 395' 11 :00 - 12:00 1.00 CASE P DECOMP Stand back DC's - LD bit, clean boot baskets (recovered brass, alum. & steel spring) - PU reverse circ. basket 12:00 - 13:00 1.00 CASE P OECOMP RU test equipment - Test casing to 3500 psi fl 30 minutes - Record on chart (lost 500 psi) monitor "OA" as before - Blow down lines - RO test equip. 13:00 - 14:00 1.00 CASE P DECOMP RIH wI boot basket assy. on 4" drill pipe f/402' to 3740' (top of sand) Obtain parameters UPWT 112k I SOWT 981 ROT 104k I RTTO 2K 14:00 - 15:00 1.00 CASE P OECOMP Ory drill on junk l' - Clean out sand I junk fl 3741' - 3790' I BPM 9.5 I PP 3080 I RPM 30 I TO 2k 15:00 - 15:30 0.50 CASE P DECOMP Pump 30 bbl high vise. polymer sweep - Displace well wI seawater I BPM 9.51 PP 2730 Printed: 11/612006 8:02:21 AM ¡. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 10/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/26/2006 15:30 - 18:00 2.50 CASE P DECOMP POH fl 3790' to 402' - Stand back drill collars in derrick - Break out I clean reverse circ baskets - Clean boot baskets (recovered pieces of black rubber, alum) 18:00 - 18:30 0.50 CASE P DECOMP MU reverse circ basket wI new dress off shoe extention - MU boot baskets I jars I drill collars 18:30 - 19:30 1.00 CASE P DECOMP RIH f/405' to 3791 (tagged sand) - Obtain parameters UPWT 115k I SOWT 98k I ROWT 105k 19:30 - 20:00 0.50 CASE P DECOMP Ory drill on junk I sand l' - Clean out junk and sand f/3792' to 3796' I BPM 10 I PP 2720 I RPM 30 20:00 - 21 :00 1.00 CASE P DECOMP Pump 30 bbl high visco polymer sweep - Circulate sweep out of hole - Pump dry job 21 :00 - 23:00 2.00 CASE P DECOMP POH fl 3796' to 405' - LD reverse circ basket I boot basket - clean baskets (recovered 1 piece alum. fl rev circ. basket I several small pieces in boot baskets) - LD BHA 23:00 - 00:00 1.00 CASE P OECOMP MU HES RBP retrieving tool - RIH to 2200' 10/27/2006 00:00 - 00:30 0.50 CASE P DECOMP RIH from 2200 to 3714 00:30 - 01 :30 1.00 CASE P OECOMP Tag RBP @ 3796' - Latch RBP - Confirm latch with 10K overpull - Release RBP - PU relax elements - Slack off confirm release - Flow check well 01 :30 - 03:00 1.50 CASE P DECOMP POH from 3800' 03:00 - 05:00 2.00 CASE P DECOMP RU test equipment - Close Blinds rams - Test casg to 3500 - Hold 30 mins - Lost 100 psi - Bump up pressure to 3500 - Hold for 45 mins lost 100 psi (Visually monitor "OA" - No leak observed) - Record on chart 05:00 - 05:30 0.50 CASE P DECOMP RO test equip. - Clear floor 05:30 - 06:00 0.50 CASE P DECOMP MU RBP retrieving O.S. - RIH wI OC's 06:00 - 07:30 1.50 CASE P DECOMP Cut & slip drilling line - Service rig 07:30 - 10:00 2.50 CASE P DECOMP RIH to 6533' 10:00 - 11 :30 1.50 CASE P DECOMP Circ. OP volume - RU test equip. - Test 7 5/8" casing to 4000 psi (Bled off 150 psi in 30 min.) - Visually monitor "OA" through valve - No leak observed - Record on chart - RD test equip. 11 :30 - 13:00 1.50 CASE P DECOMP Continue RIH to 10,240' 13:00 - 14:00 1.00 CASE P DECOMP Circulate surface to surface -7.5 bpm 1850 psi 14:00 - 15:30 1.50 CASE P OECOMP RU test equip. - Test casing to 4000 psi (monitor "OA" as before) - Record on chart - Test good 15:30 - 16:00 0.50 CASE P DECOMP RIH to 10,283' - Latch & release RBP 16:00 - 17:00 1.00 CASE P DECOMP CBU wI 7.5 bpm 2010 psi - Flow check - Well static - Pump dry job - Blow down top drive 17:00 - 20:15 3.25 CASE P DECOMP POH from 10283' to 3621' 20: 15 - 20:45 0.50 CASE N RREP DECOMP Investigate source of hydraulic oil on wall - Found small leak from EZ Torque cylinder and hoses - Clean up oil that had run down inside rig wall I beam on drillers side of rig - Estimated volume 1 quart - No oil on rig mats I ground - Reported to Spill Response Center 20:45 - 22:30 1.75 CASE P OECOMP Con't POH from 3621' to BHA 22:30 - 23:00 0.50 CASE P OECOMP Stand back DC's - LO RBP - Retrieving tool 23:00 - 00:00 1.00 CASE P DECOMP Moblize BHA to rig floor - MU 35/8" cleanout assy. 10/28/2006 00:00 - 01 :00 1.00 CASE P DECOMP MU BHA 01 :00 - 04:30 3.50 CASE P DECOMP RIH from 547' to 10,216' 04:30 - 07:00 2.50 CLEAN P OECOMP Screw in TD - Obtain parameters - PUW 230k - SOW 145k - ROT 180k - Tag top 4 1/2" tubing at 10,304' - Enter tubing wI 3.70" junk mill & PAC DP - Tag HES FasOrill plug at 10,360' - Orilling plug w/2-4k wt., 40-60 rpm, 6-11k tq - 3 bpm 370 psi. Printed: 11/6/2006 8:02:21 AM À .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-28 X-28 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 1 0/16/2006 Rig Release: Rig Number: 14 Spud Date: 11/17/1993 End: 10/28/2006 07:00 - 07:30 0.50 CLEAN P DECOMP Push plug out tail pipe - Wash down to 10,450' 07:30 - 08:30 1.00 CASE P DECOMP POH above 41/2" tubing - CBU w/6 bpm 1570 psi - 12 bph loss while pumping - Observe well f/15 min - 10 bph loss wI no pump 08:30 - 18:30 10.00 CASE P OECOMP POH LDDP - LO BHA 18:30 - 19:30 1.00 CASE P OECOMP Clear rig floor - LD Baker tools - Pull wear ring 19:30 - 21 :30 2.00 RUNCO RUNCMP RU 4 1/2" tubing running equipment - Change out bails 21 :30 - 22:30 1.00 RUNCO RREP RUNCMP Trouble shoot winch on stabbing board - RO winch - RU tugger to raise I lower stabbing board - PJSM (procedures I hazards, discuss using tugger for back up stabbing board operations) 22:30 - 00:00 1.50 RUNCO RUNCMP PU I Run 4 1/2" TC11 L-80 12.6# Tubing (total fluid lost to well 267 bbls ) 10/29/2006 00:00 - 12:00 12.00 RUNCO RUNCMP Run 41/2" L-80 12.6# tubing to 10,274' (Replaced badJt. #66 & 108 clo collar Jt. #65 & 107) 12:00 - 13:30 1.50 RUNCO RUNCMP Obtain parameters - PUW 168K - SOW 125k - Observe top of 41/2" stub at 10,304' - Slack off & tag shear screws - Shear wI 1 Ok down - Slack off & bottom out on stub wI Unique O.S. - PU & space out - LD joint # 245 - PU tubing hanger & landing joint - Land tubing - RILDS 13:30 - 14:30 1.00 RUNCO RUNCMP PJSM - RU circulating lines to annulus I tubing 14:30 - 20:30 6.00 RUNCO RUNCMP Pump 150 bbls 140 degree seawater - 270 bbls inhibited seawater @ 127 gpm 490 psi taking returns out tubing - Swap lines to Hot Oil - Pump 85 bbls diesel to IA - 2 bpm @ 700 psi - Allow to U-Tube for 1 hour - RD lines on tubing - Drop ball I rod - RU Hot Oil - Test lines - Set packer wI 4000 psi 20:30 - 00:00 3.50 RUNCO RUNCMP Test tubing to 4000 psi - 30 mins on chart - Test good - Bleed tubing to 1500 - Pressure up IA to 4000 psi - 30 mins on chart - Lost 200 psi in 30 mins - Bump up lost 60 psi in 12 mins - Bump up lost 20 psi 14 mins - Bump up lost 100 psi in 30 mins - Bleed off pressure (total fluid lost to well 447 bbls) 10/30/2006 00:00 - 03:00 3.00 RUNCO RUNCMP Install double valve on IA - Test IA to 4000 psi for 30 mins - Record on chart (lost 25 psi I test good) Bleed of IA - Tubing - Suck back diesel out of all circulating lines - RO circulating lines - LD Landing joint - Install lubricator extension - RU DSM Lubricator 03:00 - 03:30 0.50 RUNCO RUNCMP Install TWC - Test TWC to 4000 psi from top f/10 minutes- Record on chart {good) 03:30 - 06:00 2.50 RUNCO RUNCMP Blow down lines to BOPE - Suck out fluid from BOPE wI rig vac system - NO BOPE - Install cover on conveyor to rock washer 06:00 - 07:30 1.50 RUNCO RUNCMP Install adapter flange & tree on well head I prep rig fl move 07:30 - 08:30 1.00 RUNCO RUNCMP RU & test adapter flange to 5000 psi f/1 0 min. - Test tree to 5000 psi f/15 min - Record on chart 08:30 - 10:30 2.00 RUNCO RUNCMP RU OSM lubricator - Pull TWC - Install BPV - RD lubricator 10:30 - 12:00 1.50 RUNCO RUNCMP RO test equip. - Remove double valve fl "IA" - Install flanges & gauges on tree - Secure tree - Clean cellar area - Prepare for rig move - Release rig at 12:00 hrs. Printed: 11/6/2006 8:02:21 AM Scblulnberger 2: 5 zom3 NO. 4018 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth G~ (", I,' '",,:,C~ \ '. ..r'f,,\\1\..'~~&- ,"' VWi("~\' U T c... l C13 - II L{ Field: Prudhoe Bay â-- Well Job# Loa DescriDtion Date L Color CD L-04 11212895 SCMT 10/16/06 1 L-04 NIA SCMT 10/21/06 1 L-04 11422697 USIT 10/10106 1 F-12 11434752 USIT 10/19/06 1 X-28 NIA USIT 10/20106 1 AGI-10 N/A USIT 10/23/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc_ Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: 10/24/06 . . L ¡ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 7 2006 REPORT OF SUNDRY WELL OPERA TION£ Oil & Gas Cons. Cammission . . RECEIVED . 1. Operations Performed: AnChO~e AbandonD Repair WellO PIUR PerforationsD Stimulate 0 Other X re-RWO Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionO Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryO 1Q~1140 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519·6612 StratigraphicO ServiceŒJ 50-029-22394-00·00 7. KB Elevation (ft): 9. Well Name and Number: 67.88 X-28 8. Property Designation: 10. Field/Pool(s): ADL·028313 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10905 feet Plugs (measured) 4-1/2" HES FasDrill Plug @ 10361' (09/23/06) true vertical 9229.0 feet Weatherford IRBP @ 10675 (07/08/2003) Effective Depth measured 10675 feet Junk (measured) None true vertical 8999.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 45 - 155 45.0 - 155.0 1530 520 SURFACE 3446 10-3/4" 45.5# L-80 44 - 3490 52.0 - 3186.0 5210 2480 PRODUCTION 10516 7-5/8" 29.7# L-80 43 - 10556 51.0 - 8881.0 6890 4790 LINER 503 5-1/2" 17# NT-80 10402 - 10905 8727.0 - 9229.0 7740 6280 ~.~~ ';t;\!\~ ~~ ~¡r) 9 C Perforation depth: v~.. ,..__,' ~hi/ d' Measured depth: 10655-10671 True vertical depth: 8980-8995 Tubing ( size. grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 41 - 10406 Packers & SSSV (type & measured depth): 7-5/8" TIW HBBP Packer @ 10345 4-1/2" Otis HXO SSSV Nipple @ 2118 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinç¡ Pressure Prior to well operation: SI 0 0 --- 0 Subsequent to operation: SI 0 0 -- 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒJ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilD GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TSUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature h.d ;r ;t. Ii ~ Phone 564-5174 Date 10/16/06 Form 10-404 Revised 4/2004 n n , " I T\ A I I . ''''' r ..; r f \ IJ , RBDMS 8ft 0 cr I 7 ZOOfi , . . . X-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07103/2006 T/IA/OA=150010/225 Eval. T X IC comm. PPPOT-T-IC PPPOT-T 5,000 Passed PPPOT-IC Passed Sting into 7-5/8" IC test void to monitor pressure [0] on void pressure up on test void to 3,800 for 30 minutes. LOS did not require any torque to test. Sting into test void on tubing hanger, got back small amount of old test fluid, test void to 5,000 for 30 minutes. LOS did not require any torque to test. 07107/2006 T/I/O=150/20/250 MIT-OA TO 2500 FAILED Pumped 4 bbls crude to reach test pressure OA lost 1560 psi in first 15 min on test 1 and lost 1500 psi in first 15 min on test 2 could not establish LLR at 2500 psi took 1.5 bbls to keep pressure at 2500 psi for a 1/2 hr FWHP=250/20/300 07/28/2006 ***WELL SII ON ARRIVAL *** (RWO Screening) ARRIVE ON LOCATION, INSPECT AREA, BEGIN R!U TO CALIPER TBG. 07/29/2006 DRIFT TUBING WITH 3.50" G-RING, UNABLE TO PASS 3364' SLM , DRIFT TUBING WI 21/8" STEM, 3.50" CENT. & SAMPLE BAILER TO 10529' SLM, TIGHT BETWEEN 3364'- 3470' SLM CALIPER TUBING FROM 10450' SLM, PDS CALIPER! 3.375" CENT. (GOOD DATA) ***WELL LEFT SII, DSO NOTIFIED*** 08/23/2006 T/I/O=40010/200 PPPOT-T (passed) Void @ 0 psi. Tested @ 5000 psi with no pressure loss after 30 min. All LOS functioned & torqued @ 450 ft #. PPPOT·IC (passed) 50 psi on void bled to 0 psi. Tested @ 3000 psi with no pressure loss after 30 min. All LOS functioned & torqued @ 450 ft #. 09/09/2006 ** WELL SHUT IN UPON ARRIVAL** (RWO prep/pull IBP) RIG UP SIL UNIT. 09/10/2006 (RWO Prep) DRIFTED TBG WITH 3.625" SWAGE UP TO A 3.75" GAUGE RING, WORKED TIGHT AREA FROM 3320' SLM TO 3470' SLM. APPEARS TO BE SCHMOO BIULD UP IS THE SOURCE OF THE RESTRICTION. LATCHED IBP @ 10536' SLM, VERY POOR JAR ACTION, DRUG IBP TO 3700' & SHEARED PULLING TOOL, IBP FELL BACK TO BOTTOM. LATCH IBP WI 41/2" BAIT SUB WI OVERSHOT @ 10,654' SLM, PULLING VERY HEAVY. 09/11/2006 PULLED IBP FROM 10654' SLM, RUBBER WAS PEELED UPSIDE DOWN BUT ALL INTACT. DRIFT WI 3.70" CENT. SIT DOWN @ 10,663' SLM (NO OBSTRUCTIONS) SAMPLE BAILER FULL OF SCHMOO ***WELL LEFT SI*** 09/21/2006 T/I/O=140NAC/120, Temp=SI. MonitorWHP's, TBG & IA FL's (E-line). TBG FL @ 1356' (21 bbls), IA FL @ 48' (1 bbl). 09/23/2006 T/I/O = 135Nac/0 CMIT TxlA to 2000 psi PASSED (Assist E-Line) Pumped 28.6 bbls of crude down tubing to reach test pressure. Tubing lost 40 psi in the 1 st 15 min and 40 psi in the 2nd 15 min. IA lost 20 psi in the 1 st 15 min and 0 psi in the 2nd 15 min. Total losses in the 30 min test. Tubing = 80 psi. IA = 20 psi. Bleed TxlA back down. Final WHP's = 010/150 Page 1 ¡ . . . X-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/23/2006 WELL SHUT IN ON ARRIVAL. SSV WAS OPEN. INITIAL TIIIO = 20010/200 RAN 4.5" HALIBURTON FAS DRILL PLUG WITH MAX 00=3.66". SET PLUG @ 10361' RAN 1 11/16" TUBING PUNCHER LOADED 4 SPF. SHOOTING INTERVAL 10230' -10232' TIIIO BEFOR TBG. PUNCH = 010/200. NO CHANGE. POOH WITH TBG PUNCH TO RIG UP STRING SHOT (PRE-CHEM CUT) 09/24/2006 *** WELL SI ON ARRIVAL *** (fish) ATTEMPTING TO FISH E-LlNE BULLNOSE OFF STRING SHOT WI MAGNETS & FINGER BASKET FROM TOP OF FASDRILL PLUG @ 10,351' SLM...RAN 3.50 LIB TO 10,351' SLM, LT MARK ON EDGE OF BLOCK, POSSIBLY TOP OF FISH. *** JOB IN PROGRESS *** 09/24/2006 SHOT 2 STRAND X 17' STRINGSHOT AT 10274' -10291' BOTTOM NOSE ON STRINGSHOT LEFT DOWNHOLE FINAL TIIIO = 5010/200 ** Job not complete: rigged down for SL to fish bottom nose.** PAD NOTIFIED UPON DEPARTURE. 09/25/2006 WELL SHUT IN ON ARRIVAL. SSV OPEN. FUSIBLE CAP INSTALLED THAT WAS REMOVED WITH PAD OPERATORS PERMISSION. INITIAL- T/I/O= 500/300/200 CHEMICAL CUT THE TUBING WITH 3 5/8" CHEMICAL CUTTER AT 10286' IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE PACKER. MAX LENGTH=28.7'. MAX 00=3.625". WELL SHUT IN ON DEPARTURE. SSV OPEN AND CONTROL TURNED BACK OVER TO PAD OPERATOR. FUSIBLE CAP NOT RE-INSTALLED. PAD OPERATOR NOTIFIED. *****JOB COMPLETE***** 09/25/2006 (fish e-line tools) MADE SEVERAL ATTEMPTS TO FISH BULLNOSE OFF BOTTOM OF E- LINE STRING SHOT. RDMO ***JOB INCOMPLETE, E-LlNE FISH STILL IN HOLE *** 09/26/2006 T/I/O= 40010/200 - Circ Out (Pre-RWO) - Pumped 5 bbls neat meth followed by 694 bbls seawater down TBG taking returns up IA through Cosasco loop to X-22 flowtine. 09/26/2006 TIIIO=120NAC/20, Temp=SI. Monitor WHP's (pre-rig). 09/27/2006 Circ out, CMIT TxlA 2000 psi ***PASSED*** (Pre RWO) - Pumped 51 bbls 70* seawater down TBG taking returns up IA through Cosasco loop to X-22 flowline. Pressured up TxlA to 2000 psi w/3.1 bbls 45* 60/40 meth water. (1 st test) TBG lost 20 psi in 1 st 15 min and 30 psi in 2nd 15 min. IA lost 10 psi in 1st 15 min and 40 psi in 2nd 15 min. TBG lost a total of 50 psi and IA lost a total of 50 psi in 30 min test. (2nd test) - TBG lost 10 psi in 1 st 15 min and 10 psi in 2nd 15 min. IA lost 0 psi in 1 st 15 min and 20 psi in 2nd 15 min. TBG lost a total of 20 psi and IA lost a total of 20 psi in 30 min test. Bled press. Freeze protect IA w/105 bbls 60/40 meth water taking returns up TBG to X-22 flowline. Freeze protect TBG w/38 FLUIDS PUMPED BBLS 8 Diesel --- PT Surface Equipment 5 Methanol Water 6 Diesel 694 Sea Water 713 TOTAL Page 2 TREE = WELLHEAD = ,ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4" 5M CIW 11" 5M FMC BAKER 68' 41' 1519' 44 @ 6314' 10543' 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I Minimum ID = 3.725" @ 10393' 4-1/2" PARKER SWN NIPPLE I TOP OF 5-1/2" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 7-5/8" CSG, 29.7#, 10 = 6.875" I 10402' 10406' S NOTES: TIW PKR. MAY FAIL IF2100 PSI DIFF. IS EXCEEDED X-28 2118' -14-1/2" OTIS HXO SSSV NIP, ID = 3.813" I . 2950' -1 TOP OF CEMENT (4/26/06) GAS LIFT MANDRELS MD TVD DEV TYÆ VLV LATCH PORT DATE 3337 3068 40 MERLA BK 12/30/03 5888 4961 44 MERLA BK 7771 6362 41 MERLA BK 8862 7258 28 MERLA BK 9838 8171 14 MERLA BK 10181 8506 8 MERLA BK ÆRFORA TION SUMMA RY REF LOG: BHCA ON 12/02/93 ANGLEAT TOP PERF: 3@ 10557' Note: Reter to Production DB for historical pert data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 10557 - 10575 S 05/15/00 3-3/8" 6 10648 - 10655 S 05/15/00 3-3/8" 6 10655 - 10671 C 05/19/00 3-3/8" 6 10680 - 10706 S 05/15/00 I PBTD I 5-1/2" LNR, 17#, NT-80, .0232 bpt, ID = 4.892" I DA TE REV BY COMMENTS 12/06/93 MRL ORIGINAL COMPLETION 06/20/03 BMcNlTL IBP FISH 07/08/03 PW8TLP FISH IRBP, SETWFD IRBP 08/20/04 LDK/TLP SET IBP 04/26/06 DPS/PJC OA OWN SQUEEZE 05/02/06 SB/PJC OA DWN SQZ CORRECTION 10823' 10905' 10675' DA TE REV BY COMMENTS 09/12/06 JRPITLH IBP PULLED 09/23/06 RRD/PAG SET HES PLUG, TBG PUNCH 09/25/06 RRD/PAG CHEM CUT @ 10286' 17-5/8" X 4-1/2" TIW HBSP PKR, 10 = 4.0" I I HES FASDRILL PLUG (09/23/06) , 14.1/2" PARKER SWS NIP, ID = 3.813" I 14-1/2" PARKER SWN NIP, ID - 3.725" I 14-1/2" WLEG, ID = 3.958" I H ELMD TT LOGGED 04/10/94 I I SET WEA THERFORD IRBP 07/08/03 I PRUDHOE BA Y UNIT WELL: X-28 ÆRMIT No: "1931140 API No: 50-029-22394-00 SEC 7, T10N, R14E. 4887' FSL & 84' FEL BP Exploration (Alaska) . ,~ . ~"-,,oJ / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNEl); SEP 1 3 2005 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-28 Sundry Number: 306-305 3'" \ \~ \~ Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. J n Chai DATED this-ø day of September, 2006 Sincerely, Encl. - ~ ~\1~~ DIStil tf jbSTATE OF ALASKA ff Ca '/ f 7/0 b ALASKA OIL AND GAS CONSERVATION COMMZON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RÊCEy{JËO Alaska Oil & Gas Cons. Commission SEP 0 6 2006 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension -g o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development D Exploratory 193-114/' 3. Address: o Stratigraphic 181 Service 6. API Number: ./ P.O. Box 196612. Anchorage, Alaska 99519-6612 50-029-22394-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU X-28 / Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028313 67.88' Prudhoe Bay Field / Prudhoe Bay Pool 12. .. j/ j/ .. ....... .in.>· .//< ><ii i .. i. /; ........./ . .... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10905 9229 1 0823 9147 10515 None Casino Lenoth Size MD / TVD Burst Collanse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3464' 10-3/4" 3493' 3189' 5210 2480 Intermediate 1 0530' 7-5/8" 10557' 8882' 8180 5120 Production Liner 502' 5-1/2" 1 0403' - 1 0905' 8728' - 9229' 7740 6280 Perforation Depth MD (ft)/ Perforation Depth TVD (ft): Tubing Size: / Tubing Grade: Tubing MD (ft): Below IBP: 10655' - 10671' 8980' - 8995' 4-1/2",12.6# L-80 10406' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP' packer / packers and SSSV MD (ft): 10345' / 13. Attachments: 14. Well Class after proposed work: / ~ Description Summary of Proposal D BOP Sketch D Exploratory D Development ~ Service o Detailed Operations Program 15. Estimated Date for r~ ) 16. Well Status after proposed work: Commencina Ooerations: September, 15Ao06 DOil DGas D Plugged D Abandoned 17. Verbal Approval: Date\j DWAG DGINJ ~WINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Signature !\4UA /'!J.. ~ Prepared By Name/Number: Phone 564-4303 Date 9/(P Ilk Terrie Hubble, 564-4628 , / -, Commission Use Only . Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~ ... 2a') D Plug Integrity ¡y(BOP Test ~echanicallntegrity Test D Location Clearance T~s. t ßDt'E to ~C;oo I Other: r 5,A:. . ff\. L T i' ,%y~ J. LJ Subsequent Form Required: to - 40~ ~ Date rj/ð6 ((.II ~9ØMt4sSI0NE~ APPROVED BY Approved By: T.HE C :;?MMISSION Form 10-403 Revised 06/2006 L/ ........ V ~ V Vì(iIO~~ 8 ~~?'Icaœ , ORIGfNAL ~ . . Obp GI3J. X-28i Rig Workover Scope of Work: Pull 4-Y2" completion, cut and pull 7-5/8" casing, run and cement to surface new 7-5/8" casing, run 4-W L-80 "stacker-packer" completion. MASP: 2540 psi / Well Type: Injector Estimated Start Date: September 15, 2006 Pre-ri F 1 S 2 E 3 o 4 o 5 o 6 10296' . / Proposed Procedure 1. MIRU. ND tree. NU and test BOPE tGi.5. 0 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-W' tubing string to the cut. 3. Log casing for corrosion severity of 7-5/8" and top of cement in 7-5/8" x 10-3/4" annulus. /' 4. Cut and pull 7-5/8" casing from above the top of ceme/nt 5. Run and fully cement new 7 -5/S" casing to surface. 6. Run 4-W' L-SO completion with Baker S-3 packer. Position packer at -10200' MD. 7. Displace the IA to packer fluid and set the packer. S. Test tubing and IA to 3500 psi. Freeze protect to 220P' MD. 9. Set BPV. ND BOPE. NU and test tree. RDMO. / , TREE =, WB..LHEAD = ACTUA TOR = KB. B..EV = BF. B.EV = KOP= Iv1ax Angle = Datum MD = Datum TVO = 4" 5M CIW 11"5MFMC BAKER 68' 41' 1519' 44 @ 6314' 10543' 8800' SS 10-314" CSG. 45.5#, L-80, 10 = 9.953" I Minimum ID = 3~725" @ 10393' 4-1/2" PARKER SWN NIPPLE I TOP OF 5-1/2" LNR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 10402' 10406' X-28 SA OTES: TlW PKR. MAY FAIL IF 21 00 PSI DIFF. IS EXCEEDED 2118' ~4-1/2" OTIS HXO SSSV NIP, 10- 3.813" I . 2950' ~ TOP OF CEMENT (4/26/06) GAS LIFT MANDRElS MD TVD DEV TYÆ VLV LATCH PORT DATE 3337 3068 40 MERLA BK 12/30/03 5888 4961 44 MERLA BK 7771 6362 41 MERLA BK 8862 7258 28 MERLA BK 9838 8171 14 MERLA BK 10181 8506 8 MERLA BK 7-5/8" CSG, 29.7#. 10 = 6.875" I ÆRFORA TION SUMMARY REF LOG: BHCA ON 12/02/93 ANGLEAT TOP ÆRF: 3 @ 10557' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10557 - 10575 S 05/15/00 3-3/8" 6 10648 - 10655 S 05/15/00 3-3/8" 6 10655-10671 C 05/19/00 3-3/8" 6 10680 - 10706 S 05/15/00 5-1/2" LNR, 17#, NT-80, .0232 bpf, 10 = 4.892" I 10905' I PBTD I 10823' OA TE REV BY COMMENTS 12/06193 MRL ORIGINAL COMPLETION 06/20/03 BMcNITL IBP FISH 07/08/03 PlNElTLP FISH IRBP. SETWFD IRBP 08/20/04 LDKlTLP SET IBP 04/26/06 OPS/PJC OA OWN SQUEEZE 05/02/06 SB/PJC OA OWN SQZ CORRECTION OA TE REV BY COMMENTS 10326' 14-1/2" PARKER SWS NIP, IIJ = 3.813" I 10345' 7-5/8" X 4-1/2" TIW HBBPA<R, IIJ = 4.0" 10375' 10393' 4-1/2" PARKER SWS NIP, ß) = 3.813" 14-1/2" PARKER SWN NIP, ß) - 3.725" 10406' 10396' 10515' 14-1/2" WLEG, 10 = 3.958"1 H B..MD IT LOGGED 04/10/941 3.38" WEATHERFORD IBP SET 08/20/04 10675' SET WEA THERFORD IRBP 07/08/03 PRUDHOE BAY UNIT WB.L: X-28 PERMIT No: '1931140 API No: 50-029-22394-00 SEC7, T10N, R14E, 4887' FSL &84' FB. BP Exploration (Alaska) '" TREE=- 4" 5MCIVV 11"5MFMC BAKER 68' 41' 1519' 44 @ 6314' 10543' S800' SS waLHEAD = ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum lV D = X-28i Proposed Completion / 10-314" CSG, 45.5#, L-SO, ID = 9.953" I I TOP OF 5-1/2" LNRI 14-112" TBG, 12.6#, L-SO, .0152 bpf, ID = 3.95S" I 1 0402' 1 0406' 7-5/S" CSG, 29.7#, ID = 6.S75" I ÆRFORA TION SUMMARY REF LOG: BHCA ON 12/02/93 ANGLEAT TOP ÆRF: 3 @ 10557' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/S" 6 10557 - 10575 S 05/15100 3-3IS" 6 1064S - 10655 S 05/15100 3-3/S" 6 10655 - 10671 C 05/19/00 3·3IS" 6 106S0 - 10706 S 05/15100 5-1/2" LNR, 17#, NT-SO, .0232 bpf, ID = 4.S92" 10905' I PBTD I 10823' DA TE REV BY COMrÆNTS 12/06193 MRL ORIGINAL COMPLETION 06/20/03 BM;NfTL IBP FISH 0710S103 PWE/TLP FISH IRBP, SET WFD IRBP OS120/04 LDKlTLP SET IBP 04126/06 DPS/PJC OA DWN SQUEEZE 05102106 SB/PJC OA DWN SOl CORRECTION DA TE REV BY -2000' -14-1/2" HES X NIP, ID = 3.S13" ?' 14-1/2" HES X NIP, ID = 3.S13" -10,200' 7-5/S" X 4-1/2" BKR S-3 PKR ?' 4-112" HES X NIP, ID = 3.813" 10326' 4-1/2" PARKER SWS NIP, D= 3.S13" 10345' 7-5/S" X 4-1/2" TIVV HBBP PKR, ID = 4.0" 10375' 10393' 14-1/2" PARKERSWS NIP, 10= 3.S13" 14-1/2" PARKER SWN NIP, 10 = 3.725" 10406' 4-1/2" WLEG, ID = 3.95S" 10396' H B..MD IT LOGGED 04/10194 I / 10675' SET WEATHERFORD IRBP 07/0S/03 / COMMENTS PRUDHOE BA Y UNIT WB..L: X-2S PERMIT No: "1931140 API No: 50-029-22394-00 SEC 7, T10N, R14E, 48S7' FSL & S4' Fa. BP Exploration (Alaska) ) ~i~rŒ [1 !Æ~fÆ~æ!Æ ) FRANK H. MURKOWSKI, GOVERNOR AIfASKA. OIL AlWD GAS CONSERVATION COltDllSSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Carlson Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ,,/ \ \\¥ \~~ Re: Prudhoe Bay X-28 Sundry Number: 305-138 SC.ANNED JUN 1 il 2.00E; Dear Mr. Carlson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holid or weekend. A person may not appeal a Commission decision to Superior Co ess rehearing has been requested. DATED this ~y of June, 2005 Enel. ) ) June 1, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite' 1 00 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for X-28 OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain an injection waiver for well X-28i. Step Type Procedure 1 0 OA FL depress 2 F OA cement down squeeze 3 F MIT OA after WOC Well X-28i is an injector which requires a waiver for TxlA communication./An MITOA on 10/27/04 failed with a LLR of 1 bpm at 1100 psi. In order to waiver the well for injection, an OA downsqueeze must be performed. This procedure will pump a column of cement from the OA shoe to approximately 500 ft above /'/ the shoe for waiver compliance. Please contact Brian Carlson at 564-5046 with any questions. Sincerely, ~J:f-&J~ Brian H Carlson A&X Pad Production Engineer cm 6""z -f) 5" W () 1\-.,. ~ I z-/ LL'" S" ) STATE OF ALASKA ),~ 6/2/5 ALASKA OIL AND GAS CONSERVATION COMMISSIONRECE~\l~c: APPLICATION FOR SUNDRY APPROV AJ '1'1 0 .~ '700'5" 20 AAC 25.280 · Jt I'! " ,Il (. Stratigraphic D Service Œ] 9. Well Name and Number: X-28/~ 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10823 9079.5 MD TVD , 1. Type of Request: Abandon D D D Suspend D IK] D Operation Shutdown Plug Perforations Perforate New Pool 4. Current Well Class: Alter Casing Change Approved Program Repair Well Pull Tubing 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Development D P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.88 KB 8. Property Designation: ADL-028313 11. Present Total Depth MD (ft): 10905 Casing Total Depth TVD (ft): 9229.3 Length Size D D D perforate~kª Oi~ &. G 1J1wÇi~~rD ;.>' t: riis:siüß1her D Stimulate D Tim¡"W~igRl£WtJ Re-enter Suspended Well D 5. Permit to Drill Number: 193-1140 /' Exploratory D 6. API Number /' 50-029-22394-00-00 /~ Plugs (md): Junk (md): 10515,10675 None Burst Collapse CONDUCTOR LINER PRODUCTION SURFACE Perforation Depth MD (ft): Perfs Below IBP @ 105151. Packers and SSSV Type: 4-1/2" TIW HBBP-R Packer 4-1/2" MCX I-SSV 12. Attachments: 20" 91.5# H-40 5-1/2" 17# NT80S 7-5/8" 29.7# NT-95H~ 10-3/4" 45.5# NT-80 Perforation Depth TVD (ft): o bottom top 110 10905 10557 3493 Tubing Size: 4-1/2 " 12.6 # Packers and SSSV MD (ft): 1490 7740 8180 5210 Tubing MD (ft): 27 80 502 10530 3464 top 30 10403 27 29 30.0 8727.8 27.0 29.0 bottom 110.0 9229.3 8881.6 3188.8 Tubing Grade: L-80 10406 470 6280 5120 2480 13. Well Class after proposed work: 10345 2118 Exploratory D DevelopmentD /' ServiceŒ] 15. Well Status after proposed work: Oil D ~~D PluggedD AbandonedD WAG [!f GINJD WI~ WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Brian Carlson Description Summary of Proposal ŒJ Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: June 15,2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Printed Name Signature Brian Carlson 7~ ld- ~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D Other: ~ 4c4- ' Subsequen '-- ORIGI~JAL Form 10-403 Revised 11/2004 Contact Title Phone Production Engineer 564-5046 6/1105 Sundry Number: 3oy"-/~ Location Clearance D BY ORDER OF ~¡; ...h r THE COMMISSION Date: i" t¡ t).:::. RBDMS 8Ft !I ~,~ n ~ 7nos SUBMIT IN DUPLICATE ) TREE = ~'5M crvv W8...LHEAD = 11" 5M FMC ACfUii;'TQR"';; " '''''ï3AkËR "kï3~""ËLËV"'; n... .... ....". .... ~. f!iaï BF: ELEV ~ " 41' '¡(ÒF> = "......" "" ""., ,"'_. 1sfii ..~ax ~~~~_,=",~~~~,?~~4' Datum MD = 10543' DatumTVD = 8800' SS 10-3/4" CSG, 45.5#, L-80, 10 = 9.953" 1-1 3490' ~ Minimum ID = 3.725" @ 10393' 4-1/2" PARKER SWN NIPPLE I TOPOF5-1/2"LNR-4 10402' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 0 =3.958" 1-4 10406' ') X-28 SAFETY NOTES: llW PKR. MAY FAIL IF 21 00 PSI DIFT. IS EXCEEDED (I) 2118' 1-14-1/2" OTIS HXO SSSV NIP, ID = 3.813" I ~ GAS LIFT MANDRELS ST M) ND DEV TYPE VL V LA Ta-I PORr DATE 6 3337 3068 40 MffiLA BK 12/30/03 L 5 5888 4961 44 MffiLA BK 4 7771 6362 41 MffiLA BK 3 8862 7258 28 MffiLA BK 2 9838 8171 14 MffiLA BK 1 1 01 81 8506 8 MffiLA BK I 10326' H4-1/2" PA~ERSWS NIP, ID= 3.813" 1 :8: 10345' H7-5/8" X4-1/2" TIW HBBPPKR, 0 =4.0" ~ I ~ ~ 1~ 10375' H4-1/2" PA~ERSWS NIP, ID= 3.813" 10393' H4-1/2" PA~ERSWNNIP, ID= 3.725" I 10406' H4-1/2" WL83, ID = 3.958" I 10396' H EUvD TT LOGGID 04/10/94 10515' H3.38" WEATHffiFORD IBP SEr 08/20/04 þ..- 7-5/8" CSG, 29.7#,10 = 6.875" 1-1 1 0556' ~ .. PffiFORA TION SUwtv1ARY REF LOG: BHCA ON 12/02/93 ANGLE AT TOP ÆRF: 3@ 10557' N:>te: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA lE 3-3/8" 6 10557 - 10575 S 05/15100 3-3/8" 6 10648 - 10655 S 05/15100 3-3/8" 6 10655 - 10671 0 05/19/00 3-3/8" 6 10680 - 10706 S 05/15100 I PBTD H 10823' 5-1/2" LNR, 17#, NT-80, .0232 bpf, ID= 4.892" H 10905' [)o\ TE REV BY COwtv1ENTS 12/06/93 MRL ORIGINAL COM PLETION 06126/01 RN/TP CORRECTONS 06120/03 BMcNllLr IBP FISH OU)8/03 PWE/1LP FISH IRBP, SETWFD IRBP 08120/04 LCK/TLP SET IBP DA lE REV BY ~ I 10675' HSETWE'A1HERFORDIRBP07/08/03 I ~ COMtvENTS PRLDHOE BA Y LNrT WELL: X-28 PffiMff No: 1931140 A R No: 50-029-22394-00 SEC 7, T10N, R14E, 4887' FSL & 84' Fa.. BP Exploration (Alaska) STATUS: X-28 (PTD 1931140) Subject: STATUS: X-28 (PT~lOr . From: "NSU, ADW We]] Integrity Engineer" <NSUADWWclUntcgrityEnginccr@BP.com> Date: Fri, 27 Aug 2004 15:53:30 -0800 To: "AOGCC - Winton Aubert (E-mail)" <winton_aubert@admin.ståte.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <bob.:..fleckenstein@adrnin.state.ak.us>, "AOGCC - Jim Regg (E-mail)" <jim _regg@adrnin.state.ak.us> . CC: "Mielke, Robert L." <robert.mielke@BP.com>, "Rossberg,RSteven" <RossbeRS@BP.com>,. "GPB, Well Pads BAX" <GPBWel1PadsBAX@BP.com>,. "Watson~Jennifer D" <WatsonJD@BP.com>, "NSU, ADW Well Operations Supervisor". . . . :/ <NSUADWW ellOperationsSupervisor@BP .com> ~ "Reeves, Donald .F" <ReevesDf@BP.com>. "Engel, Hany R" <EngeJHR@BP.com>, "Olsen. Cla.Fk:A"<OlsenCA@BF-~é()Jn>.' . Hello Jim, Winton & Bob. An IBP was set in X-28 and a subsequent MIT-Tubing passed to 2500 psi on 8/26/04. Summary of recent events: 07/24/04: Bled IAP from 1420 to 20 psi, IAP increased 660 psi in 30 min. 07/25/04: MIT-IA Passed to 2500 psi 08/20/04: IBP set in liner below tubing tail 08/26/04: MIT-T Passed to 2500 psi At this point, we have conflicting test results. The IAP equalizes with the tubing pressure fairly rapidly, but both an MIT-T and MIT-IA pass. One option is to pull the IBP and repeat the bleed down test. We wanted to review well conditions prior to pulling the IBP to see if you recommend any additional pressure testing. Attached is an MIT form, was and TIO & Inj plots. Let me know if you have any questions. Joe «MIT PBU X-28 08-26-04.xls» Plot. jpg» «X-28.pdf» «X-28 TIO Plot.jpg» «X-28 Inj -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Tuesday, July 27, 2004 9:28 AM To: AOGCC - Winton Aubert (E-mail) Cc: Rossberg, R Steven; Hasebe, Brant M; Watson, Jennifer Operations Supervisor; Reeves, Donald F; Engel, Harry R Subject: X-28 Status D; NSU, ADW Well Hi Winton. Well X-28 (PTD #1931140) is exhibiting indications of a 1-way leak into the IA. The Pad Operator reported the IA pressure had equalized with the tubing pressure. Several bleeds confirmed the IA repressures to the tubing pressure. An MITIA conducted on 7/25/04 passed to 2500 psi. This would indicate a 1-way leak into the IA. Current plans are to evaluate the failure, demonstrate 2 competent well barrier systems and apply for a sundry. The proposed evaluation program is as follows: - Set TTP, conduct an MITT. - If MITT fails, run an LDL to locate the leak point and eval for repair. - If MITT passes, pull the TTP, set an IBP in the liner and eval packer condition. - ID secondary well barrier system with either an MITOA or a No-Flow test. Please note the cost of this evaluation work could exceed $80M. Any feedback to this approach is appreciated. Attached is a wellbore schematic. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. 10f2 9/1 0/2004 9:25 AM STATUS: X-28 (PTD 1931140) Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1l54 Email: NSUADWWellIntegrityEngineer@bp.com PBU X-28 Content-Description: MIT PBU X-28 08-26-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: X-28.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: X-28 no Plotjpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: X-28 Inj Plotjpg Inj Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 2 of2 9/10/20049:25 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / X Pad 08/26/04 Joe Anders 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = SaltWater Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes 1= Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU X-28 08-26-04.xls TREE = 4" 5M CIW WB.LHEAD = 11" 5M FMC A CTl.LI\ TOR = BAKER KB. ELEV - 68' BF. ELEV = 41' KOP- 1519' Max Angle = 44 @ 6314' Datum MD = 10543' DatumlVD = 8800' SS 10-314" COO, 45.5#, L-80, ID = 9.953" Minimum ID = 3.725" @ 10393' 4-1/2" PARKER SWN NIPPLE TOPOF 5-1/2" LNR 4-1IZ'l13G, 12.6#, L-BO, .0152 bpf, D = 3.958" 7-5/8" COO, 29.7#, ID = 6.875" PERFORATION SUMvlARY REF LOG: BHCA. ON 12/02/93 ANGLE AT TOP ÆRF: 3 @ 10557' IIt>te: Refer to Production DB for historical perf da1a SIZE SPF INTERII AL Opn/Saz ()ð. "IE 3-318" 6 10557 - 10575 S 05115/00 3-318" 6 10648 - 10655 S 05115/00 3-318" 6 10655 -10671 0 05119/00 3-318" 6 10680 -10706 S 05/15/00 10823' 5-1IZ' L~, 17#, NT-80, .0232 bpf, ID= 4.892" H 10905' X-28 . SAFElY NOTES: l1W PKR. MAYFAILIF 21 00 PSI DIFf'. IS EXCEEDED 2118' 4-1/2" OTIS HXO SSSV NP, ID = 3.813" ST fvD 6 3337 5 5888 4 7771 3 8862 2 9838 1 10181 GAS LIFT MANI:RELS lVD DBI TYÆ VLV LATCH 3068 40 MERLA BK 4961 44 MERLA BK 6362 41 MERLA BK 7258 28 MERLA BK 8171 14 MERLA BK 8506 8 MERLA BK 10326' 10345' 10375' 10393' 10406' PORr DATE 12/30/03 4-1/2" F¥\RKERSWS NIP,ID= 3.813" 7-5/8" x 4-1/2" TIWHBBPPKR, D = 4.0" 4-1/2" F¥\RKERSWS NIP,ID= 3.813" 4-1/2" F¥\RKERSWN NIP, ID= 3.725" I 10396' H ELfvDTT LOGGED 041101941 4-1/2" \lVL83, ID = 3.958" 10675' DATE REV BY COMIlÆNTS ()ð. TE REV BY CO~ENTS 12/06/93 MRL ORIGINAL COMPLETION 03/02/01 SIS-MD ANAL 06/26/01 RWTP CORRECTIONS 06/20/03 BMc WTU- IBP ASH 07/OS/03 IW&'TLP ASH IRBP, INFD IRBP @ 10675' 11/20/03 JDWfTLP ADD DATE RUG WAS SET SET WEA THERFORD IRBP 07/08103 FRUŒlOE BA Y UNT WB.L: X-28 ÆRMrrNo: 1931140 A PI No: 50-029-22394-00 SEC7, T10N, R14E; 4887 FSL &84'FEL 8P Exploration (Alaska) X-28 no Plotjpg (JPEG Image, 915x281 pixels) X-28110 'P1ot 4000 ,I ,;aoo ¡ I 2¡ÐOO ... ... 1 ,000 I of 1 +Tbg .'A ..... OA OOA . OOOA 9/1 0/2004 9:26 AM ,-., en Q) ~ "õ.. - 00 N ~ or¡ - 0\ oJ ~ S - 0 ~ p... ...... '-' M 0.. ";:? 0 c::: 5 00 N X t . ooo'z; '5 it c: ti f - '11 t lot . t (:) . .~ . )( ~ t ~ I + Õ :! + AvgWHJP,psig 000' ~ OOO'tU 000'9 000'9 OOO't QOO'Z 0.-&18:10. '1MS/1I8+Mdlt98f189 (I) « 0 :;s « l"- N 0; "<t 0 0 ~ 0 - --.. 0\ 0 v 0 -@ (I() ~ 8 -i -~ C:! v -~ ~ -I ..- -I 0 ..- 8 o~ - c..., 0 [F\\'d: X-28 Status] Subject: [Fwd: X-28 Status] From: Winton Aubert <winton - aubert@admin.state.ak.us> Date: Tue. 27 Ju12004 11:12:43 -0800 To: James B Regg <jim_regg@admin.state.ak.us> Another. w.4-t5 .:IN~~f2-- -------- Original Message -------- Subject: X-28 Status Date: Tue, 27 Jul 200~ 09:28:02 -0800 From: NSU, ADW Well Integrity Engineer <~JSUADWWolllntcgrityEnglneer~EP.com> To: AOGCC - Winton Aubert (E-mail) '~','.'lntc'n ;;¡ubert')'cì.dpllI1.stëtte.3.k.1J3> Cc: Rossberg, R Steven <: PossbeRS':."8F. com>, Hasebe, Brant M cH¿-¡sebeE:'r"1:l,BP. e,:::'m:>, v-latson, Jennifer D d'7at:::~clnJr}'1."EP.cC'n\>, NSU, ADv-l Well Operations SupervIsor <l']SUì\D\rMe 1 1 Opera t i c,nsSu,per'/ i SOi.-':;,8P. com>, Reeves, Donald F .< ReevesDUì.'EF. corn:>, Engel, Harry R .:: F.nge 1 HP':",>GP. cern> Hi Winton. Well X-28 (PTD #1931140) is exhibiting indications of a I-way leak into the IA. The Pad Operator reported the IA pressure had equalized with the tubing pressure. Several bleeds confirmed the IA repressures to the tubing pressure. An MITIA conducted on 7/25/04 passed to 2500 psi. This would indicate a I-way leak into the IA. Current plans are to evaluate the failure, demonstrate 2 competent well barrier systems and apply for a sundry. The proposed evaluation program is as follows: - Set TTP, conduct an MITT. - If MITT fails, run an LDL to locate the leak point and eval for repair. - If MITT passes, pull the TTP, set an IBP in the liner and eval packer condition. - 10 secondary well barrier system with either an MITOA or a No-Flow test. Please note the cost of this evaluation work could exceed S80M. Any feedback to this approach is appreciated. Attached is a wellbore schematic. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-115..,l Pager: (907) 659-5100, xl154 Email: N~~U^Ç...í¡.~V.ì.::l.llnte..J~it::.:En].1 n-=: E l".1ibp . ::'qrn «X-28.pdf» ¡ Content-Type: applicationJoctet-streanl X-28.pdf . ! Content-Encoding: base64 1 of 1 7/27/2004 12:55 PM TREE = W8.LHEAD = A CTl.L£\ TOR = KB ELEV = BF ELEV = KOP= Max Ange = Datum MD = Datum1VD = 4" 5M CIW 11" 5M FMC BAKER 68' 41' 1519' 44 @ 6314' 10543' 8800' SS X-28 SAFETY NOTES: llW PKR. MAY FAIL IF 2100 PSI DIFF.IS EXCEEDED 8 2118' H4-1/2" OTIS HXO SSSV NIP, 10 = 3813" 1 10-3/4"CSG, 45,5#, L-80,ID= 9953" 1-1 3490' ~ ~ L S T fv[) 6 3337 5 5888 4 777 1 3 8862 2 9838 1 10181 GAS LIFT MANDRELS NO DEV TYPE VLV LATCH 3068 40 MERLA BK 4961 44 MERLA BK 6362 41 MERLA BK 7258 28 MERLA BK 8171 14 MERLA BK 8506 8 MERLA BK PORT DATE 12/30/03 Minimum ID = 3.725" @ 10393' 4-1/2" PARKER SWN NIPPLE :8: I 1 10326' 1-14-112" PA RKER SWS NIP, 10 = 3 813" 1 :8: 1 1 0345' H7-5/8" x 4-1/2"TIWHBBPPKR, D =4,0" 1 \! 1 10375' H4-1I2" PARKERSWSNIP,ID= 3,813" 1 1 10393' H4-1/2" PARKERSWNNIP,ID= 3,ì25" 1 1 1 0406' H4-1/2" WLEG, 10 = 3 958" 1 1 10396' H EUvDTT LOGGED 04/10/941 1 TOPOF 5-1/2" LNRI--1 10402' 1 4-1/2"1BG,12,6#,L-80, 0152bpf,D=3,958" 1--1 10406' 1 ~ 7-5/8" CSG, 29 7#,10 = 6875" l-i 10556' ~ ~ PERFORA TION SUIVTv1A RY REF LOG: BHCA ON 12/02/93 A NGLE AT TOP ÆRF: 3 @ 10557' I'bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz [)A.1E 3-3/8" 6 10557 - 10575 S 05/15/00 3-3/8" 6 10648 - 10655 S 05/15/00 3-3/8" 6 10655-10671 0 05/19/00 3-3/8" 6 10680 - 10706 S 05/15/00 ~ 1 10675' HSET W~ 1HERFORD IRBP 07/08/03 1 I PBTO H 10823' ~. 5-112" LNR, 17#, NT-80, ,0232 bpf, 10 = 4,892" 1-1 10905' DATE REV BY COMMENTS 12/06/93 M RL ORIGINAL COMPLETION 03/02/01 SIS-MD RNAL 06/26/01 RNiTP CORRECTIONS 06/20/03 BMcN'TLI- IBP RSH 07/08/03 FWElTLP RSH IRBP, WFD IRBP @ 10675' 11/20/03 JDW/TLP ADD DATE RUG WAS SET [)A. TE REV BY COI\iTv1ENTS PRUDHOE BA Y UNIT W8.L' X-28 ÆRMIT No' 1931140 A PI No: 50-029-22394-00 SEC7, T10N, R14E 4887' FSL & 84' FEL 8P Exploration (Alaska) 5rf" 11: 1(C4 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU CPF-1 A 07/25/04 Arend 1 Brake Packer Depth Well CPF-1A Type Inj N T.V.D. 3679 Tubing P.T.D. 1842270 Type Test P Test psi 1500 Casing Notes: 4-Year MIT, CPF1 Class 1\ disposal well Pretest Initial 15 Min. 30 Min. 260 260 260 260 Interval 4 30 2500 2500 2500 P/F P Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE I NJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) M IT Report Form Revised: 05/19/02 2004-0725_MIT _KRU- CPF-1 A,xls 7/27/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test .jC;C- 71z1/èf Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us:andJim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 1C-123 07/23/04 Brake / Arend Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-123L Type Inj N T.V.D. 3688 Tubing 1050 2500 2400 2375 Interval 0 P.T.D. 2010840 Type Test P Test psi 1500 Casing 120 120 120 120 P/F P Notes: MIT-tubing on long string with tubing plug in hole Well 1C-123S Type Inj N T.V.D. 3688 Tubing 850 2500 2325 2260 Interval 0 P.TD. 2010840 Type Test P Test psi 1500 Casing 120 120 120 120 P/F P Notes: MIT-tubing on short string with tubing plug in hole Well 1C-123S Type Inj TV.D. T-S 2260 2500 2500 2500 Interval 0 P .TD. 2010840 Type Test Test psi 1500 T-L 2375 2600 2600 2600 P/F P Notes: Combo MIT T x IA with tubing plugs in both strings IA 120 2520 2460 2450 Well Type Inj TV.D. Tubing Interval P.TD. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1C-123 07-23-04-1 ,xis 7/27/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jlJ2 "7 (1-ê(CA Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 1C-123 07/25/04 Brake 1 Arend Packer Depth Pretest Initial 15 Min. 30 Min. We1l1C-123L Type Inj N T.V.D. 3688 Tbg-S 1000 2500 2450 2410 Interval 0 P .1.0. 2010840 Type Test P Test psi 1500 Tbg-L 350 350 350 350 P/F P Notes: MIT-tubing on long string with tubing plug in hole IA 200 250 250 250 Well 1C-123S Type Inj N T.V.D. 3688 Tubing 1050 1050 1050 1050 Interval 0 P.T.D. 2010840 Type Test P Test psi 1500 Casing 350 2500 2350 2300 P/F P Notes: MIT-tubing on short string with tubing plug in hole IA 250 300 300 300 Well P.T.D. Notes: T.V.D. Test psi 1500 T-S 1000 1250 1250 1250 T -L 600 850 850 850 IA 1 00 2500 2450 2425 45 Min Read LS/SS/IA = 12501850/2425 Tubing Casing Interval 0 P/F P Well 1C-123S Type Inj N T.V.D. P.T.D. 2010840 Type Test P Test psi 1500 Notes: MITIA with tubing plugs in both strings Type Inj Type Test Interval P/F Well P.T.D. Notes: Type Inj Type Test T.V.D. Tubing Test psi 1500 Casing Interval P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1C-123 07-25-04-1 ,xis 7/27/2004 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SuspendD Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations[!] Perforate New Pool D 4. Current Well Class: Perforate 0 VarianceD Annular DisposalD Stimulate 0 Time Extension 0 OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 193-1140 Name: BP Exploration (Alaska), Inc. 3. Address: P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.88 8. Property Designation: ADL-0028313 11. Present Well Condition Summary: Total Depth measured 10905 true vertical Effective Depth measured true vertical Casing Conductor Liner Production Surface Length 80 502 10530 3464 Perforation depth: Development D Stratigraphic D 9. Well Name and Number: X-28 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service Œl 6. API Number 50-029-22394-00-00 feet 9229.3 feet 10675 Plugs (measured) Junk (measured) 10675 feet 8999.5 feet None Size 20" 91.5# H-40 5-112" 17# NT80S 7-5/8" 29.7# NT-95HS 10-3/4" 45.5# NT-80 MD TVD Burst Collapse 30 110 30.0 - 110.0 1490 470 10403 - 10905 8727.8 - 9229.3 7740 6280 27 - 10557 27.0 - 8881.6 8180 5120 29 - 3493 29.0 - 3188.8 5210 2480 Measured depth: 10655 -10670,10670 -10671 4-1/2" 12.6# L-80 @ RECEIVED DËC 1 7 Ali/$ka a,l & 2003 Gas Cons C . Anc . ommlSsifJ True vertical depth: 8979.5 - 8994.48, 8994.48 - 8995.48 Tubing ( size, grade, and measured depth): 27 - 10406 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - 4-1/2" MCX I-SSV 4-1/2" TIW HBBP-R Packer @ 2118 @ 10345 Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 7081 520 4505 1891 400 4916 15. Well Class after proposed work: Exploratory D Development D ServiceŒ) 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG 0 GINJŒl WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: Title Production Technical Assistant Phone 564-4657 Date 12/17/03 ORIGINAL Form 10-404 Revis~~E[J/ DEC $ 12003 ~Bfb , ' . , ( ( . , X-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/25/03 PULLED MCX SSSV @ 21021 WLM OS/25/03 Pump 216 bbls scmoo-b-gone soak 3 hrs pump 160 bbls water flush from skid to well 06/20/03 WEATHERFORD IRBP SET WAS UNSUCCESSFUL. IRBP HAD A PARTIAL SET AND PULLED OFF DURING POOH (WEATHERFORD WEAKPOINT SHEARED AT APPROX 9750 FT) RIH TOOL = HEAD/AH38/GO ADAPTER/WEATHERFORD SETTING TOOL WITH CCUIRBP = 29.3 FT X 3.375in MAX OD. DEPTH CORRELATED 06/20/03 Accidental setting of IBP @ 9750' 06/21/03 (FISH OUT IBP) RAN 3.6in 2.6in BELLGUIDE & 1-3/8in PULLING TOOL TO IBP @ 103741 SLM RECOVERED IBP W/ ALL BANDS AND RUBBERS ***RET WELL TO PAD OP TO PUT ON INJ*** 06/21/03 TIO=vac/O/O Freeze protect tbg (fish IBP) Pump 40 bbls of 50/50 methanol/water down tbg. Final T10=1 00/0/0 . 07/08/03 SET WEATHERFORD INFLATABLE RETRIEVABLE BRIDGE PLUG W/ THERMAL COMPENSATOR TOP OF ELEMENT AT 106751. 1 in FISHING NECK SET AT 106731. DEPTH CORRELATED TO SLB IPROF DATED 5/26/2002. WELL SHUT IN APPROX 20 HOURS PRIOR TO RIH WITH IBP. DID NOT TAG TD. TAGGED IBP AFTER SETTING TO VERIFY POSITION. FLUIDS PUMPED BBLS 216 Schmao-Be-Gane 160 Water 8 Neat Methanal 40 50/50 Methanal/H2O 424 TOTAL Page 1 . '. II' ( f . Æ I TREE = 4" 5M CrN X-28 SAFETY NOTES: llW PKR. MAYFAlLlF2100 PSI DIFF. IS EXCEEDED W8..LHEAD = 11" 5M FMC A CTLiA. TOR = BAKER KB. ELEV = 68' BF. ELEV = 41' KOP= 1519' Max Anae = 44 (â). 6314' Datum MD = 1 0543' DatumTVD = 8800' SS 2118' 8 10-314" CSG, 45.5#, L-80, ID = 9.953" 3490' ST MD 6 3337 5 5888 4 7771 3 8862 2 9838 1 10181 Minimum ID = 3.725" @ 10393' 4-1/2" PARKER SWN NIPPLE 1 TOPOF 5-1/2" LNRI 14-1/2" TaG, 12.6#, L-80, .0152 bpf, D =3.958" I 10375' 10393' 10326' 10345' 10402' 1 0406' 4-1/2" OTIS HXO SSSV I\IP, ID = 3.813" GAS LIFT MANDRELS lV D DBI TYPE VL V LA Ta-i 3068 40 MERLA BK 4961 44 MERLA BK 6362 41 MERLA BK 7258 28 MERLA BK 8171 14 MERLA BK 8506 8 MERLA BK PORT DATE 12130¡{)3 4-1/2" PARKERSWS NIp, ID= 3.813" 7-518" X 4-1/2" TIW I-BBP PKR, D = 4.0" 4-1/2" PARKERSWS NIP, ID= 3.813" 4-1/2" PARKERSWN NIP, ID= 3.725" 10406' 4-1/2" WLEG, ID =3.958" 1 10396' H ELIvDTT LOGGED 04/10/941 7-5/8" CSG, 29.7#, ID = 6.875" I 10556' PERFORATION SUMMARY REF LOG: BHCA ON 12/02/93 ANGLE AT TOP ÆRF: 3@ 10557' f\bte: Refer to Production DB for historical perf data SIZE SPF INTERV AL Qpn/Sqz DATE 3-318" 6 10557 - 10575 S 05/15/00 3-3/8" 6 10648 - 10655 S 05/15/00 3-3/8" 6 10655 - 10671 0 05/19/00 3-318" 6 10680 - 10706 S 05/15/00 10675' 1 PBTD I 10823' 5-112" LNR, 17#, NT-80, .0232 bpf, ID = 4.892" 1--1 10905' DATE REV BY COMMENTS DATE RBI BY COMMENTS 12/06/93 MRL ORIGINAL COMPLETION 03/02/01 SIS-MD ANAL 06/26/01 RN'TP CORRECfIONS 06/20/03 BMcN'TU- IBP ASH 07/08/03 FW 6'TLP ASH IRBP, WFD IRBP @ 10675' 11/20/03 JDW/TLP ADD DATE A..lX3 WAS SEr SET WEA lHERFORD IRBP 07/08103 mUDHOE BA Y UNIT W8..L: X-28 ÆRMIT No: 1931140 A PI No: 50-029-22394-00 SEC 7, T1 ON, R14E, 4887' FSL & 84' FEL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor Chairman DATE' May 20, 2002 ' ~(~,/[v/-.,_"-"..."~ ~ SUBJECT: Mechanical Integrity Tests THRU' Tom Maunder BPX P.I. Superviso¢''~' ~ G/%"O-) X Pad PBU FROM: Chuck Scheve Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL Welli X-28 P.T.D.] 193-114 Notes: Well! X-29 P.T.D.I 193-139 Notes: We'llI . X-33 P.T.D.! 196-'~44 Notes: w~llI x-3~ P.T.D.I 196-167 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type,nj.Isl,]v.D. I J Tubingl 000 I 000 ! 000 I 000 4' myp~te~tI P t T.stps~l 2~68 ICasingI 0 122901230012300 ,!,, P~FIP ~ I s ! T.V.D. l esae l Tubing! ~TS 1~7S I'~000 !. ~50 I,.,e~,l4_1 Type lnj'I P I mestpsil 2135 lCasingI 900 I 2220 I 2170 I 2150 I P/FI P !~ Type test i Type lnj.I S ! T,V.D. J ezss I Tubing I ~100 I ~00 i ~00 I 1~00 l,nte~a,I 4 ~ Type testJ P I TestpsiI 2197 l CasingI 675 I 2440 I ..23~ [ 2360 I P/F J ~ ,vpetestI ~ l,estpsiI 2a~4 ICasin~I 2s0 ! 23~0 I 2340 ! 2340I ~F ! ~ Type INJ. Fluid Codes F = FRESH'WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test' M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval i= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs X Pad and wimessed the 4-year MIT on wells X-28, X-29,X-33 and X-36. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed' 4 Number of Failures: 0 Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. SCANNED JUN ~ 'A ,2002 MIT PBU X Pad 5-20-02 CS.xIs 6/3/02 MEMORANDUM TO: THRU: FROM: Julie Heusser, Commissioner' State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 16, 2000 Safety Valve System Tests BPX / PBU Misc. WAG well Prudhoe Oil Pool Tom Maunder, ~-'~'~~'~'~-~UB~CT: P. I. Supervisor ~l ~~0~- ~i John H Spaulding, Petroleum Inspector January 16, 2000: I traveled to BPX's Prudhoe Bay Unit to witness WAG wells SVS test on various pads. These are well that normally come due in this portion of the 6 month cycle. The AOGCC SVS test report is attached for reference. As noted 4 pads were visited with 5 wells being tested. All surface equipment passed quite readily but 3 out 5 SSSV's failed. These have been added to the wireline list for tomorrow 1-17-01, and should be ready to be retested by no later than 1-18-01. Merv Littelow and helpers did a very good job considering that this was the helpers first time in conducting these tests. SUMMARY: I witnessed the sVs test on BPX's Prudhoe Bay Unit: PBU S pad 2 wells 6 components, 2 failures PBU M pad 1 well 3 components,, 0 failures PBU P pad 1 well 3 components, 1 failures PBU × pad 1 well 3 components, 0 failures Attachment: svs bpx m pad 1-16-01js Svs bpx p pad 1-16-01 js Svs bpx x pad 1-16-01js Svs bpx s pad 1-16-01js Non Confidential r Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: John H. Spaulding AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Prudhoe Bay / PBU / M-pad Separator psi: LPS HPS 1/16/01 Well - Permit Separ set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE M-03 1710180 M-04 1710230 M-05A 1970810 M-06A 1930930 M-07 1790370 M-08 1800860 M-09A 1970310 M-10 1810290 M-11 1810570 M-12 1810630 M-13 1801240 M-14 1801090 M-15 1810850 M-16 1810860 M-18B 1930540 M-19A 1921370 M-20A 1971990 M-21A 1930750 M-22 1830540 M-23 ~ 1830550 M-24 1830570 M-25 1860650 . M-26A 1920280 M-27A 1930860 M-28 1860740 2000 1950! P P P WAG M-29 1890020 M-30 1920300 IM-31 1920320 M-32 1920330 M-33 1941160 M-34 1941330i · M-38 1941410 [] 90 Day 1/18/01 Page 1 of 2 svs-bpx-m-pad 1-16-0 ljs.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE Wells: Components: Failures: Failure Rate: [] 90 var Remarks: 1/18/01 Page 2 of 2 svs-bpx-m-pad 1-16-01js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littelow AOGCC Rep: John H. Spaulding Submitted By: John H. Spaul.d ~ Date: Field/U~ad: Prudhoe Bay / PBU/)dC-pad Separator psi: LPS HPS 1/16/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i P-01 1920920 P-02 1930840 P-03A 1972280 P-04 1910760 P-05A 2000510 P-06A 1972240 P-07 1941640 P-08A 2000850 :P-09 1930580 ,. P-10 1910520 2000 1950 P P 9 P-11 1910290 P-12A 1950220 P-13 1901110 P-14 1910070 P-15 1901760 P-16 1901630 P-17 1901550 P-18 1901450 P-19 1901360 P-20A 1960040 P-21B 1970640 P-22 1931210 P-23 1931120 P-24 1970540 P-25 1970260 P-26 1962000 Wells: Components: Failures: Failure Rate: Remarks: 1/18/01 Page 1 of 1 svs-bpx-p-pad 1-16-0 ljs.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littlelow AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Prudhoe Bay / PBU / X-pad Separator psi: LPS HPS 1/16/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLE X-01 17905401 X-02 1790690! . ,, X-03A 1980860 X-04 1790890! X-05 1791040 X-06 1800090 X-07 1800130 ' X-08 1800360 X-09 1800280 . , X-10' 1800430{ X-11A 1990780 X-12 1800440! X-13A 1930650 X-14A 1921430 X-15 1800740 X-16 1811720 X'17 1811690 X-18 1811620 X-19B 1961300 X-20 1940670 X-21A 1991080 X-22 1931300 X-2~ 1840610 X-24A 1991250 X-25 1840340 X-26 1840300 Ix-27 1840690 , X-28 1931140 2000 2000 P P P WAG , X-29 1931390 X-30 1950410 X-31 1931980 X-32 1931620 ,, X-34 1931720 X-35-. 1931990 1/18/01 Page 1 of 2 svs-bpx-x-pad 1-16-0 ljs.xls ~ 'T'mlTIFTr' ~-,~-,,i,.?, ~ ...... .~-.~11-~~-~ ..... ~ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE X-36 ~ 1961670 Wells: Components: Failures: Failure Rate: Remarks: 1/18/01 Page 2 of 2 svs-bpx-x-pad 1-16-0 lj s.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littlelow AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld. Date: Field/Unit/Pad: _Prudhoe Bay / PBU / S-pad Separator psi: LPS HPS 1/16/01 Well Permit Separ : Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE S-01B 1952020 S-02A 1941090 . S-03 1811900 S-04 1830790 S-05A 1951890~ S-06 1821650! 2000~ 1950 P P P WAG S'-07A 19209801 S-08A 1982280 S-09 1821040 S-11B 1990530 ,, S-12A 1851930 S-13 1821350 , S-14 1821290 ' S-15 1840710 S-16 1840840 S-17A 1911190 S-18 1841250 S-19 1861160 .I S-20 1861470 S-200 1972390 S-21 1900470 s-23 1901270 S-24A 1982450 S-26 1900580 S-27A 1951000 S-28A 1951730 S-29A 1960110 S-30 1900660 S-32 1901490 S-33 1921020 ~-34 1921360 2000 2000 P P 9 WAG S-35 1921480 S-36 1921160 S-37 1920990 , 1/18/01 Page 1 of 2 svs-bpx-s-pad 1-16-01js.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLW ! S-38 1921270 S-40A 1961250 S-41 1960240 S-42 i960540 i'S'43 1970520 S-44 1970060 Wells: Components: Failures: Failure Rate: [] 9o Day Remarks: 1/18/01 Page 2 of 2 svs-bpx-s-pad 1-16-0 lj s.xls ~--. STATE OF ALASKA ALASKA ...~L AND GAS CONSERVATION CO~viMISSlON APPLICATION FOR SUNDRY APPROVAL !1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate ' [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ,/- v' v/ 393' SNL, 83' WEL, SEC. 07',T10N, R14E, UM At top of productive interval 1110' SNL, 4942' WEL, SEC. 07, T10N, R14E, UM At effective depth 1115' SNL, 4953' WEL, SEC. 07, T10N, R14E, UM At total depth 1115' SNL, 4952' WEL, SEC. 07, T10N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphi/~ [] Service v' 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10905v~' et 9229 ~feet 10823 feet 9147 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented 6. Datum Elevation (DF or KB) KBE - 67.88' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number X-28 9. Permit ,~nber 93-114 10. APl Number ,/" 50- 029-22394 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool RECEIVED N 0V 0 1999 Al~b,Oil & Gas Cons. Commission Anchorage MD 80' 20" 11 yds Arcticset 3464' 10-3/4" 1100 sx PF 'E', 375 sx Class 'G' 10530' 7-5/8" 300 sx Class 'G' 502' 5-1/2" 100 sx Class 'G' TVD 110' 110' 3493' 3189' 10557' 8882' 10403'-10905' 8728'-9229' Or, GINAL Perforation depth: measured 10557'-10575', 10648'-10670', 10680'-10706' true vertical 8882'-8900', 8973'-8994', 9004'-9030' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10406' Packers and SSSV (type and measured depth) TIW 7-5/8" x 4-1/2" Hydraulic Latched Perm. Packer at 10345'; 4-1/2" Otis 'HXO' SSSV Nipple at 2118' 13. Attachments (~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation December 3, 1999 16. If proposal was verbally approved 15. Status of well classifications as: J~ Oil J~J Gas [--J Suspended Service Water Injection v// Name of approver Date approved Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Ted Stagg Title CT Drilling Engineer Commission Use Only Date ////~/.~ Conditions of Approval:oog¥ Notify. Commission so representat,ve' may witness I Approva, No...,~'/.. f,¢~o¥o.,/eC~ .~ Plug ~ntegrity '~ BOP Test "/( Location clearance ~t ~;Cmh~il;iilnteg rity ~R~J~eJ~NANLcS~dsN:e~~;!n~U ant f° rm req u i re d 10 t-~"'O'-~' Ap he Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate a eare.d rvtces rilling Date: November 8,1999 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re' Well X-28i Prep for CT Sidetrack Well X-28i is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prepare X-28i for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. 1. A Mechanical Integrity Test will be performed. 2. A whipstock drift will be run. :3. E-Line will be used to set a mechanical whipstock in the 7" liner at approx. 10,630' MD. 4. Service coil will be used to pump approx 25 bbls cement to abandon the existing Sag River and Ivishak perfs. 5. Abandonment cement will be pressure tested to 2200 psi with AOGCC witness prior to milling the window with drilling coil. 6. Approx. 45 feet of open hole will be drilled and left open hole for injection. No liner will be run. Steps 3, setting the whipstock is scheduled for Dec. 3, 1999. Step 5, cementing the existing perfs, is scheduled to be performed by service coil on Dec. 4, 1999, and the milling/drilling operation will commence with drilling coil on Dec. 10, 1999. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center RECEIVED r:iOV 0!) 1999 Naska Oil & Gas Cons. Commissior~ Anchorage TREE: 4" ClW standard 5M BAKE R: ACTUATOR WELLHEAD: 11", 5M, FMC UNIVERSAL SLIMHOLE CSG, 10-3/4", I 3'490'l 45.5#/ft, BTC KOP @ '1000' Max Angle @ 44 TUBING, 4-1/2", 12.6#/ft, L-80, NSCT TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT X-28ai Proposed Completion KB. ELEV = 68' BF. ELEV= 41' 4-1/2" OTIS HXO SSSVNI 2118' I RECEIVED I ' ~ch0~ge GAS LIFT MANDRELS ( Merla W/1" BK LATCH) N° MD(BKB) TVDss Deg 6 3337' 3068' 40.0 5 5888' 4961' 44.2 4 7771' 6362' 40.7 3 8862' 7258' 27.7 2 9838' 8171' 14.4 1 10181' 8506' 8.4 Caution: the TIW packer in this well may fail if more than 2100 psi differential pressure is exceeded. I 5-1/2" LINER TOP I 10,402' 7-5/8" x 5-1/2-, L-8o, TIW, LINER HGR, (NO LINER TOP PKR) i 10,556,I 29.7#,, NSCC 4-1/2 "SWS" NIPPLE MIN ID 3.813 TIW 7-5/8"X 4-1/2", HYD LATCHED, PERM PACKER :~-1/2 "SWS" NIPPLE MIN ID 3.813 4-1/2 "SWN" NIPPLE MIN ID 3.75O 4-1/2" WLEG ELMD I 10,326' ] I 10,345' I 10,375' I I 10,393' I 0,406' 10,396' I Top of whipstock approx. 10,630' PERFORATION SUMMARY ISIZE SPF INTERVAL O :~EN/SQZ'D 3-3/8" 6 10,557'-10,575' OPEN 3/23/96`/ 3-3/8" 6 10,648'-10,670' OPEN 4/11/94 3-3/8" 6 10,680'-10,706' OPEN 4/11/94- PBTD I 10,823' I~ LINER, 5-1/2", 17#/ft, ! 10,905' NT80, NSCC Sag R. perfs to be cement squeezed. 3 3/4" open hole, approx. 45 ft long, to be left open hole for injection. Abandonment cement to be downsqueezed past whipstock ';'~'.~:;c~;~?~_.- ~L.~.~w~-;~ - F..?::: -,~.~:~"~-~ -' --~-'-. '-:* -.¥{ STATE OF ALASKA ALASK/~-~:::~!L AND GAS CONSERVATION COMMISSIOr' ..... REPORT O'. SUNDRY WELL OPEh,. TIONS 1. Operations performed: Operation shutdown__ Stimulate x Plugging__ Pull tubing Alter casing __ Repair well Perforate__ Other 2. Name of Operator BP Exploration (Alaskaj Inc. 3. Address P. 0. Box 196612, Anchora_Qe, Alaska 99519-6612 4. Location of well at surface 393'SNL, 83' WEL, SEC. 7, TION, R14E At top of productive interval 1110' SNL, 4942' WEL, SEC. 7, TION, R14E At effective depth 1115' SNL, 4953' WEL, SEC. 7, TION, R14E At total depth 1115' SNL, 4952' WEL, SEC. 7, TION, R14E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = ~7.8~' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number X-28 (11-7-10-14) 9. Permit number/approval number 93-114 / 10. APl number 50.029-22394 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10905 feet Plugs (measured) 9229 feet 10823 feet Junk (measured) 9147 feet Casing Length Structural -- Conductor 110' Surface 3466 Intermediate 10530 Production -- Liner 9901 Perforation depth: measured Size Cemented 20" 11 vds Arctic set 10-3/4" 1100 sx PF "E"/375 sx 7-5/8" 300 sx Class "G" 5-1/2" 100 sx Class "G" 10648'- 10670', 10680'- 10706' Measured depth 137 3493 10557 10403-10905 True verticaldepth BKB 137 3189 8882 8728-9229 true vertica§ubsea 8973'- 8994', 9004'- 9030' Tubing (size, grade, and measured depth) 4-1/2", L-80 to 10406' Packers and SSSV (type and measured depth)Packer @ 10345' SSSV @2118' 13. Stimulation or cement squeeze summar~6ee Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations I ¢ Oil__ Gas__ Suspended.__ 17. I hereby, c4~rtif, y-;that t_he foreg~,~g,is true add c,¢~ct to the best of my knowledge. Signed' '"/~/~,~ .,~/~~~~~ Title TechnicalAssistant IV Form 10-404 Rev 06/1~/§§ Service Water !niector S U BM iTD~tNeDdL~' I~C{~T~~1 X-28 DESCRIPTION OF WORK COMPLETED Stimulation Operation 05/17/98 A Liner Wash was performed using the following fluids: SUMMARY Shut in well and Rig in hole with 3.5" jet swirl nozzle. Dry tagged crust at 10,685'. Put well on injection at 1.8MBPD. Jetted through crust with water. PUH and jetted liner and perfs to a depth of 10,796' with 24 bbls of acid. Over displaced acid with 125 bbls of water. Jetted Sag pers with 36 bbls of diesel/xylene and over displaced with 105 bbls of water. Pulled out of hole and left well on injection. C/O to 10,976' CTMD. Fluids Pumped BBES. Description 35 Methanol 34 Diesel/Xylene 24 7% HCL/20% Xylene 330 2% KCL with FR 423 Total Pumped LARRY GRANT Attn. ALASKA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 May 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ECC No. ~1'~;L G-16"{44-11-11-13) 1 PLS FINAL BL+RF Run ~ 1 1130.08 ? ~'~/ B-i0/~il-05-i0-i4) Q~_}[ R-04~(22-05-ii-i3) ~4~ H-iT'J%4-iS-ii-i3 > 1PLS FINAL BL+RF Run # 1 2413.02 1 CN FINAL BL+RF Run # 1 2452.06 1 PLS FINAL BL+RF Run ~ 1 3385.03 1CN FINAL BL+RF Run # 1 4112.05 1PFC/PERF FINAL BL*RF Run # 1 1PLS FINAL BL+RF Run # 1 1PLS FINAL BL+RF 4468.06 t CN FINAL BL+RF 5609.04 i CN FINAL BL+RF Run # 1 5627.13 ~ ~TS ~INAL BL+RF Run # 1 5665.11 i PLS FINAL BL+RF Run # 1 6090.05 1 PLS FINAL BL+RF Run # 1 6103.05 Run # ! 6234.05 Run # 1 6624.03 i PFC/PERF FINAL BL+RF Run # i i GR/CCL FINAL BL+RF Run ~ 1 6667.00 6670.00 Cent/ N.aY 2] 199~ P~ease_ s£gn ~nd return to: Attn. Rcdn~v_= =. ~ _Daulson %Testern ~'~= Logging ServLces 5600~ ~ Streen Suite 201 Anchorage, AK 9~518 / Received by: /~~ ~~/i, Da~e: Oil & S~ Cons. A,qchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 1 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL X-28 (i1-07-:0-i4) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF ECC No. Run # 1 1984.06 Run # 1 4735.03 Run # 1 5746.06 Run # 1 6103.04 Run # 1 6631.00 Run # 1 6633.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ Or FAX to (907) 563-7803 Date: PNRMiT nA 93-114 '~:'"' ~ '"'~ 91-1'14 ~FL/GR 93-114 ~©C~c~ .... .ivl~iiai Well ._=oleg±cai Materi-~!s Inventory !0053~10900, OH-DiFL COMP DATE~ 04/'11/94 11/17/93-12/07/93 0-!0~71,~. HWD, EHS L i0100~--10900 L i0100-i0900 L i0150~I0770 L I0~5~= ~-10780 L 10600-10789 .... ~STVD L 10414-10807 L 10100-10900 Page~ 1 Date' 10/13/'95 RUN DATE_RECVD 04/15/94 04/15/94 04/~5/94 12/16/93 04/29/, 10/12/94 04/29/94 04/29/94 12/16/93 Are dr'./ ditch samples required? yes .~~d recei~~yes no Was the well cored? yes ysis a~o:.escr~ption received? yes no Are well tests required?~/ye ' Receive. d?--yes Well is in compliance __~__~__ Initial COHHENTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 4 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PL/INJPROF. FINAL BL 1 PL/INJPROF. RF SEPIA 1 PL~INJPROF. FINAL BL 1 PL/INJPROF. RF SEPIA 1 PL/INJPROF. FINAL BL 1 PL/INJPROF. RF SEPIA 1 PL/INJPROF. FINAL BL 1 PL/INJPROF. RF SEPIA 1 GR/CCL FINAL BL 1 GR/CCL FINL.RF SEPIA ECC No. Run # 1 4948.01 Run # 1 Run # 1 5802.04 Run # 1 Run # 1 6021.06 Run # 1 Run ~ 1 6103.03 .Run # 1 Run # 1 6123.01 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ A~~y D. Paulson Received~/ ~~/ ~.~.~_~~ Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 27 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: Y-36 (41-27-11-13) DESCRIPTION 1 CN/GR FINAL BL --~ CN/GR FINAL RF SEPIA X-28 (11-07-10-14) 1 SBT/GR/CCL FINAL BL 1 GR/CCL JEWL.FINAL BL -T~ SBT/GR/CCL RE SEPIA _-1 GR/CCL JEWL.RF SEPIA 1 PFC/PERF FINAL BL ~PFC/PERF RF SEPIA 1 GR/CCL JEWL.FINAL BL /1 GR/CCL JEWL.RF SEPIA 1 PFC/PERF FINAL BL /~ PFC/PERF RF SEPIA 1 DIFF.TEMP. FINAL BL /1 DIFF.TEMP. RF SEPIA ~"'llq X-28 (11-07-10-14) 1 PFC/PERF FINAL BL /~ PFC/PERF RF SEPIA ~(O..-C~/ H-21 (42-21-11-13) i PFC/PERF FINAL BL -~ PFC/PERF RF SEPIA ~'~[~ F-42 (22-35-12-13) 1 CN/GR FINAL BL FINAL RF sEPIA ~-!\~ K-11 (32-33-12-14) 1 CN/GR FINAL BL //1 CN/GR FINAL RF SEPIA 1 PFC/PERF FINAL BL · i' PFC/PERF RF SEPIA ECC No. Run # 1 6054.03 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6103.01 5608.03 6168.01 4952.01 4112.03 6103.02 5973.02 5953.04 6189.00 6178.01 Cont/ ~/~c3~ R-34 (13-34-12-13) 1 PFC/GR/CCL FINAL BL ~'1 PFC/GR/CCL RF SEPIA Run # 1 Run # 1 6083.05 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson RECEIVED .£':9 Received by: A laekaiOil.:&~ Gas, ~o~. i Oor//..r//~ ' Date: /~l'lO~Or~ .... .,/.t~/"/ Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 27 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL Y-36 (41-27-11-13) DESCRIPTION 1 CN/GR FINAL BL CN/ R FINAL RF SEPIA X-28 (11-07-10-14) 1 SBT/GR/CCL FINAL BL 1 GR/CCL JEWL.FINAL BL -/~ SBT/GR/CCL RF SEPIA _~1 GR/CCL JEWL.RF SEPIA 1 PFC/PERF FINAL BL ~' PFC/PERF RF SEPIA q~~ X-35 (11-12-10-13) ~12Jo R-21 ?[ -- ZP-- H-04 1 GR/CCL JEWL.FINAL BL /1 GR/CCL JEWL.RF SEPIA 1 PFC/PERF FINAL BL zd 1 DIFF.TEMP. FINAL BL /1 DIFF.TEMP. RF SEPIA ~--I[q X-28 (11-07-10-14) 1 PFC/PERF FINAL BL PFC/PERF RF SEP' A 1 PFC/PERF FINAL BL ~'0~[%c~ F-42 (22-35-12-13) 1 CN/GR FINAL BL ~\ ? K-11 (32-33-12-14) C!.~,~ ~q~ H-33 (32-21-11-13) 1 CN/GR FINAL BL //1 CN/GR FINAL RF SEPIA 1 PFC/PERF FINAL BL ~' PFC/PERF RF SEPIA Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 FCC No. 6054.03 6103.01' 5608.03 6168.01 4952.01 4112.03 6103.02 5973.02 5953.04 6189.00 6178.01 CoLt/ ~\c~ R-34 (13-34-12-13) 1 PFC/GR/CCL FINAL BL J'l PFC/GR/CCL RF SEPIA Run # 1 6083.05 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: RECEIVED .29 Date: ,~'~rlehl~rSUe ...... ..~ Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SI..ISPEI'~ED [] ABANDONED [] SERVICE [] Water lniector 2. Name of Operator 7. Permit Number BP Exploration r~ D ! ~_ i ~ j /~ ! 93.114 3. Address U I \ ! L2 i I L 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22394 4. Location of well at surface 9. Unit or Lease Name 393' SNL, 83' WEL, SEC. 7, TION, R14E ?' .:i~;,,,....: ~i~.i ~i~, i' ! ~~ ' Prudhoe Bay Unit At Top Producing Interval ]1~'--~'~lr~i~ 10. Well Number X-28(11-7-10-14) 1110'SNL, 4942' WEL, SEC. 7, TION, R14E ! .. ir:~ 11. Field and Pool 1115' SNL, 4952' WEL, SEC. 7, TION, R14E ~.- 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 67. 88' I A DL 28313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/17/93 12/1/93 4/11/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set J21. Thickness of Permafrost 10905' MD/9229' TVD 10823' MD/9147' TVD YES [] NO [~J 2118'feet MDJ 1900' (Approx.) 22. Type Electric or Other Logs Run DIFL/BHCS/GR/CNT/TEMP/MWD 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-¥OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 11 yds Arcticset 10-3/4" 45.5# NT8OLHE 29' 3493' 13-1/2" 1100 sx PF "E"/375 sx "G" 7-5/8" 29. 7# NT95HS 27' 10557' 9-7/8" 300 sx Class "G" 5-1/2" 17# NTSOS 10403' 10905' 6-3/4" 100 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter3-3/8" 6 spf 4-1/2", L-80 10406' 10345' MD TVD 10648'-10670' 8973'-8994' 10680'- 10706' 9004'-9030' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protected annulus w/83 bbls diesel 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 4/11/94 J Water Inject/on Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS~OIL RATIO I i'EST PERIOD Flow Tubing Casing Pressure .?.ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ct oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOL~ MARKERS ~-ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 10555' 8811' Shublik 10575' 8831' Top Sadlerochit 10648' 8904' HOT 10710' 8966' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~'"~ I.~_~. ~'~' .,.~/(~. Title Drillioc~ Enoineer Suoervisor Date ~L//?_./ /(7..'[ L~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ~ E C E~V E Form 10-407 Gas Cons. Commission Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: X-28I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/17/93 01:00 SPUD: 11/17/93 07:00 RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 11/17/93 ( 1) TD: 110' ( 110) MOVE RIG. MOVE RIG. N/U DIVERTER. MW: 8.5 VIS: 0 11/18/93 (2) TD: 1580' (1470) 11/19/93 (3) TD: 3010'(1430) 11/20/93 ( 4) TD: 3510' ( 500) 11/21/93 ( 5) TD: 3510' ( 0) 11/22/93 (6) TD: 5636'(2126) 11/23/93 ( 7) TD: 6560' ( 924) 11/24/93 (8) TD: 7922' (1362) 11/25/93 (9) TD: 8511' ( 589) DRLG. MW: 9.0 VIS:300 RIG ACCEPTED @ 01:00 HRS, 11/17/93. TEST DIVERTER. SPUD WELL @ 07:00 HRS, 11/17/93. DRLG F/ 105'283'. POOH. P/U BHA. DRLG F/ 283'-991'. POOH. CHANGE BHA. DRLG F/ 991'-1580'. DRLG. MW: 9.4 VIS:150 DRLG F/ 1580'-2054' CBU. POOH. CHANG BHA. RIH. DRLG F/ 2054'-2714'. CB6. POOH. CHANGE BHA. RIH. REA, F/ 2623'-2714'. DRLG F/ 2714'-3010'. CIRC. MW: 9.4 VIS:150 DRLG F/ 3010'-3510'. CBU. SHORT TRIP TO HWDP. CIRC. POOH. L/D BHA. RIH W/ 10-3/4" CSG. CIRC. DRLG. MW: 9.6 VIS: 48 CIRC. PUMP 75 BBLS WATER, 1100 SX (425 BBLS ) LEAD CMT, 375 SX (77 BBLS) TAIL CMT. DISP W/ MUD. BUMP PLUG W/ 2200 PSI. TOP JOB W/ 20 BBLS CMT. N/D DIVERTER. N/U BOPE. TEST BOPE. OK. RIH. CIRC. TEST CSG. OK. DRLG CMT, FLOAT EQUIP. SHORT TRIP. MW:10.0 VIS: 46 DRLG CMT, FLOAT EQUIP, 10' NEW HOLE. CIRC. LOT (13.9 PPG EMW). DRLG F/ 3520'-4596'. CBU. SHORT TRIP TO SHOE. DRLG F/ 4596'-5636'. CBU. SHORT TRIP TO SHOE. DRLG. MW:10.0 VIS: 45 SHORT TRIP. REAM TO BTM. DRLG F/ 5636'-6201' CBU. POOH. CHANGE BIT, BHA. RIH. DRLG F/ 6201'-6~60' DRLG. MW:10.1 VIS: 45 DRLG F/ 6560'-7240'. CIRC. SHORT TRIP 12 STDS. DRLG F/ 7240'-7922'. DRLG. DRLG F/ 7922'-8092'_ CIRC. POOH. REAM TO BTM. DRLG F/ 8092'-8511' MW:10.1 VIS: 47 CHANGE BHA, BIT. RIH. WELL : X-28I OPERATION: RIG : NABORS 22E PAGE: 2 11/26/93 (10) TD: 9001' ( 490) 11/27/93 (11) TD: 9550' ( 549) RIH. MW:10.0 VIS: 43 DRLG F/ 8511'-8960' CIRC. SHORT TRIP 12 STDS. DRLG F/ 8960'-9001' POOH. CHANGE BIT. RIH. DRLG. MW:10.0 VIS: 45 RIH. REAM TO BTM. DRLG F/ 9001'-9550'. 11/28/93 (12) TD: 9852' ( 302) 11/29/93 (13) TD:10559' ( 707) DRLG. DRLG F/ 9550'-9793' F/ 9793'-9853' MW:10.1 VIS: 46 CBU. POOH. CHANGE BIT. RIH. DRLG SHORT TRIP. MW:10.2 VIS: 48 DRLG F/ 9852'-10559'. CIRC. SHORT TRIP 20 STDS. 11/30/93 (14) TD:10559' ( 0) RUN CSG. MW:10.2 VIS: 48 CIRC. POOH. TEST BOPE. RIH W/ 7-5/8" CSG. 12/01/93 (15) TD:10559' ( 0) 12/02/93 (16) TD:10905'( 346) 12/03/93 (17) TD:10905 PB: 0 12/04/93 (18) TD:10905 PB:10823 12/05/93 (19) TD:10905 PB:10823 P/U DP. MW:10.2 VIS: 0 RIH W/ 7-5/8" CSG. LAND CSG. CIRC. PUMP 5 BBLS WATER, 50 BBLS BJ SPACER, 300 SX (61.44 BBLS) PREMIUM CMT W/ .2% CFR-3, .2% HALAD-344, .1% HR-5. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. INSTALL PACKOFF. TEST SAME. TEST BOPE. RIH W/ BIT, BHA. POOH. MW: 8.8 VIS: 42 RIH. CIRC. TEST CSG. OK. DRLG FC, CMT, FS. DRLG F/ 10559'-10905'. TD WELL @ 01:00 HRS, 12/2/93. CIRC. SHORT TRIP 5 STDS. CIRC. POOH. RELEASE F/ LNR. MW: 8.9 WBM POOH. R/U ATLAS. LOG RUN: DIFL/BHC/GR/CNT/TMP. R/D ATLAS. RIH W/ 5-1/2" NT-80 LNR. CIRC. RIH W/ LNR ON DP. CIRC. PUMP 20 BBLS WATER, 70 BBLS 11 PPG SPACER, 21 BBLS 15.7 PPG PREM CMT. DISP W/ MUD. BUMP PLUG W/ 3500 PSI. CIRC. MW: 9.0 WBM RELEASE F/ LNR. POOH 10 STDS. POOH. L/D RUNNING TOOL. RIH W/ BIT, BHA. CIRC. DRLG CMT TO 10403' CIRC. POOH. RIH W/ BIT, BHA. REPAIR PIPE HANDLER. MW: 8.5 Seawater CIRC. WASH TO 10763'. DRLG CMT F/ 10763'-10823' (PBTD). CIRC. TEST CSG. OK. CIRC. DISP WELL TO SEAWATER. TEST CSG. OK. POOH, L/D DP. TEST BOPE. SEAL ON HYDRIL GAVE OUT. REPAIR SAME. WELL : X-28I OPERATION: RIG : NABORS 22E PAGE: 3 12/06/93 (20) TD:10905 PB:10823 TEST TREE. MW: 8.5 Seawater RIH W/ 4-1/2" L-80 COMP ASS'Y. TAG LNR HGR. SPACE OUT. LAND TBG. N/D BOPE. N/U TREE. TEST TREE. 12/07/93 (21) TD:10905 PB:10823 MOVE RIG. MW: 8.5 Seawater INSTALL LUB. SET HBBP PKR. SHEAR @ 1600 PSI. TEST PKR @ 4000 PSI. TEST TBG, ANNULUS. OK. PUMP 83 BBLS DIESEL F/P. INSTALL BPV. SECURE WELL. RIG RELEASED @ 14:00 HRS, 12/6/93 14:00 HRS. MOVE RIG TO X-34. SIGNATURE: (drilling superintendent) DATE: Gas Cons. Ancho~ age BAKER HUGHES INTEQ MWD S U RVEYS - 0.00' - 1 0,484' E M S S U RVEYS - 1 0,565' - 1 0,871' BP EXPLORAT[ON (Alaska) [nc. Pad X 28 slot #28 Prudhoe Bay North Slope, Alaska SURVEY L [ ST I NG by Baker Hughes INTEQ Your ref : EMS <10565 - 10871> Our ref : sw/4129 License : Date printed : 15-Dec-93 Date created : 15-Dec-93 Last revised : 15-Dec-93 Field is centred on 708179.340~5930615.440,999.00000~N Structure is centred on n70 14 33.605,w148 39 36.642 Slot location is n70 14 29.740,w148 39 39.084 Slot Grid coordinates are N 5939734.445, E 665808.229 Slot local coordinates are 393.00 S 84.00 W Reference North is True North BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 1 Pad X,28 Your ref : EMS <10565 - 10871> Prudhoe Bay,North Slope, Alaska Last revised : 15-Dec-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.01 110.00 0.00 0.00 110.00 0.00 N 0.00 E 0.00 0.01 222.00 0.30 123.50 222.00 0.16 S 0.24 E 0.27 -0.20 314.00 1.80 89.30 313.98 0.28 S 1.89 E 1.70 -1.80 406.00 2.10 90.70 405.93 0.28 S 5.02 E 0.33 -4.88 499.00 2.10 108.30 498.87 0.84 S 8.34 E 0.69 -8.05 591.00 1.80 99.50 590.81 1.60 S 11.37 E 0.46 -10.89 683.00 1.10 107.20 682.78 2.10 S 13.64 E 0.79 -13.03 776.00 1.10 94.90 775.77 2.44 S 15.38 E 0.25 -14.68 868.00 1.00 100.20 867.75 2.66 S 17.05 E 0.15 -16.28 961.00 0.70 98.80 960.74 2.89 S 18.41 E 0.32 -17.58 1047.00 1.20 297.40 1046.74 2.56 S 18.13 E 2.18 -17.36 1140.00 3.50 285.10 1139.65 1.37 S 14.52 E 2.52 -14.03 1235.00 5.40 272.80 1234.36 0.40 S 7.26 E 2.23 -7.06 1329.00 6.80 291.80 1327.84 1.89 N 2.33 W 2.59 1.96 1424.00 8.40 291.50 1422.00 6.52 N 14.01 W 1.68 12.61 1519.00 9.90 289.70 1515.79 11.82 N 28.15 ~ 1.61 25.58 1615.00 11.70 286.90 1610.08 17.43 N 45.24 ~ 1.95 41.37 1708.00 13.30 281.30 1700.88 22.26 N 64.75 ~ 2.16 59.70 1802.00 14.90 283.00 1792.05 27.10 N 87.13 ~ 1.76 80.84 1896.00 17.10 280.20 1882.40 32.27 N 112.51 W 2.48 104.88 1989.00 18.80 278.10 1970.87 36.80 N 140.81 ~ 1.96 131.90 2084.00 21.40 275.30 2060.08 40.56 N 173.23 ~ 2.92 163.12 2179.00 26.30 279.90 2146.95 45.78 N 211.24 ~ 5.51 199.57 2273.00 30.70 279.50 2229.54 53.33 N 255.44 W 4.68 241.70 2369.00 33.00 278.40 2311.08 61.19 N 305.48 W 2.47 289.51 2464.00 33.70 271.10 2390.47 65.48 N 357.45 ~ 4.29 339.85 2559.00 36.70 273.20 2468.09 67.57 N 412.16 ~ 3.40 393.29 2654.00 38.40 267.20 2543.43 67.71 N 469.99 ~ 4.24 450.16 2749.00 39.30 265.10 2617.42 63.70 N 529.44 ~ 1.68 509.36 2843.00 38.80 262.30 2690.42 57.21 N 588.29 W 1.95 568.42 2937.00 40.80 261.60 2762.64 48.78 N 647.86 ~ 2.18 628.54 3032.00 41.30 258.10 2834.29 37.78 N 709.25 ~ 2.48 690.90 3128.00 40.10 257.00 2907.07 24.29 N 770.38 ~ 1.46 753.46 3223.00 39.40 256.60 2980.11 10.42 N 829.52 ~ 0.78 814.13 3319.00 39.60 257.00 3054.19 3.52 S 888.97 W 0.34 875.12 3413.00 39.50 258.40 3126.67 16.27 S 947.45 ~ 0.95 934.94 3445.00 38.90 259.10 3151.47 20.22 S 967.29 ~ 2.33 955.16 3576.00 39.20 258.80 3253.20 36.04 S 1048.28 ~ 0.27 1037.68 3670.00 38.90 259.10 3326.20 47.39 S 1106.41 ~ 0.38 1096.90 3766.00 39.90 257.40 3400.38 59.80 S 1166.06 W 1.53 1157.81 3859.00 42.00 257.40 3470.62 73.10 S 1225.54 W 2.26 1218.71 3954.00 42.80 257.40 3540.78 87.07 S 1288.05 ~ 0.84 1282.72 4049.00 42.70 257.70 3610.54 100.98 S 1351.02 ~ 0.24 1347.16 4143.00 42.00 258.10 3680.01 114.25 S 1412.94 ~ 0.80 1410.46 4237.00 41.80 257.70 3749.97 127.41 S 1474.32 W 0.36 1473.20 4332.00 42.00 257.70 3820.68 140.92 S 1536.31 W 0.21 1536.61 4426.00 41,80 256.60 3890.65 154.88 S 1597.51 g 0.81 1599.33 4521.00 41.90 257.40 3961.41 169.14 S 1659.27 W 0.57 1662.64 4615.00 41.80 257.70 4031.43 182.66 S 1720.51 ~ 0.24 1725.31 All data is in feet unless otherwise stated Coordinates from slot #28 and TVD from wellhead. Vertical section is from N 0.88 ~ 0.15 on azimuth 259.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ BP EXPLORATION (Alaska) Inc. Pad X,28 Prudhoe Bay, North Slope, Alaska Measured Inclin. Azimuth True Vert. R Depth Degrees Degrees Depth C 4710.00 41.90 258.10 4102.20 4805.00 41.90 258.40 4172.91 4899.00 41.70 258.40 4242.98 4994.00 42.70 258.40 4313.36 5090.00 43.00 258.40 4383.74 5184.00 43.00 259.50 4452.49 5279.00 42.50 258.40 4522.25 5373.00 43.80 258.10 4590.83 5467.00 44.20 260.50 4658.45 5561.00 44.20 261.60 4725.84 5656.00 43.90 260.50 4794.12 5751.00 43.80 261.90 4862.63 5846.00 43.60 262.60 4931.31 5938.00 43.70 261.90 4997.88 6033.00 44.00 259.80 5066.40 6126.00 44.20 258.10 5133.18 6220.00 44.20 259.10 5200.57 6314.00 44.50 258.10 5267.79 6408.00 43.40 258.80 5335.47 6502.00 42.50 258.10 5404.27 6598.00 41.30 257.70 5475.72 6693.00 40.70 257.00 5547.42 6787.00 41.00 257.70 5618.52 6881.00 40.80 259.50 5689.58 6977.00 40.80 258.80 5762.25 7070.00 40.40 260.50 5832.86 7165.00 39.70 261.60 5905.58 7258.00 40.30 261.90 5976.83 7353.00 40.40 262.30 6049.23 7449.00 41.50 262.30 6121.73 7543.00 42.10 261.20 6191.81 7636.00 41.90 261.20 6260.92 ~r732.00 41.50 261.90 6332.60 7827.00 39.60 261.60 6404.78 7922.00 38.60 262.60 6478.50 8017.00 37.80 260.50 6553.16 8114.00 37.40 261.60 6630.02 8208.00 36.70 259.50 6705.04 8301.00 35.50 259.80 6780.18 8396.00 33.80 260.20 6858.33 8491.00 32.60 260.90 6937.82 8586.00 31.90 260.90 7018.16 8679.00 30.60 260.50 7097.67 8774.00 28.70 262.30 7180.23 8870.00 26.80 263.70 7265.18 8963.00 25.60 264.70 ~48.63 9059.00 24.50 265.10 7435.60 9153.00 22.10 264.00 7521.93 9248.00 21.00 263.70 7610.28 9342.00 20.70 264.70 7698.13 SURVEY LISTING Page 2 Your ref : EMS <10565 - 10871> Last revised : 15-Dec-93 E C T A N G U L A R Dogleg Vert 0 0 R D I N A T E S Deg/lOOFt Sect 195.95 S 1782.48 W 0.30 1788.67 208.87 S 1844.60 g 0.21 1852.09 221.47 S 1905.97 W 0.21 1914.73 234.30 S 1968.48 g 1.05 1978.53 247.43 S 2032.43 ~ 0.31 2043.80 259.71 S 2095.35 W 0.80 2107.90 272.07 S 2158.64 W 0.94 2172.38 285.16 S 2221.58 ~ 1.40 2236.65 297.28 S 2285.73 ~ 1.82 2301.94 307.48 S 2350.47 ~ 0.82 2367.45 317.75 S 2415.71 W 0.86 2433.48 327.82 S 2480.75 W 1.03 2499.26 336.67 S 2545.78 ~ 0.55 2564.83 345.23 S 2608.70 ~ 0.54 2628.26 355.70 S 2673.67 ~ 1.56 2694.06 368.10 S 2737.19 ~ 1.29 2758.77 381.06 S 2801.42 W 0.74 2824.29 394.05 S 2865.84 ~ 0.81 2889.98 407.11 S 2929.75 ~ 1.28 2955.21 419.93 S 2992.50 W 1.08 3019.24 433.37 S 3055.19 ~ 1.28 3083.32 447.02 S 3116.00 ~ 0.80 3145.60 460.48 S 3175.99 W 0.58 3207.03 472.64 S 3236.32 ~ 1.27 3268.56 484.45 S 3297.92 W 0.48 3331.28 495.33 S 3357.45 ~ 1.26 3391.80 504.84 S 3417.84 ~ 1.05 3452.91 513.42 S 3477.00 W 0.68 3512.65 521.87 S 3537.92 W 0.29 3574.10 530.30 S 3600.27 ~ 1.14 3636.95 539.30 S 3662.27 ~ 1.01 3699.56 548.82 S 3723.7'/ W 0.22 3761.76 558.20 S 3786.94 W 0.64 3825.59 567.06 S 3848.06 W 2.01 3887.30 575.30 S 3907.40 ~ 1.24 3947.16 583.92 S 3965.50 W 1.60 4005.87 593.13 S 4023.96 W 0.80 4065.03 602.42 S 4079.82 ~ 1.54 4121.~ 612.27 S 4133.73 ~ 1.30 4176.45 621.65 S 41~.92 W 1.80 4230.46 630.20 S 4238.23 ~ 1.33 4282.47 638.22 S 4288.28 ~ 0.74 4333.15 (:~6.01 S 4335.89 W 1.42 4381.39 653.06 S 4382.35 ~ 2.21 4428.36 658.52 S 4426.71 ~ 2.09 4472.97 662.68 s 4467.56 W 1.37 4513.90 666.29 S 4508.04 ~ 1.16 4554.38 669.81 S 4545.05 W 2.59 4591.42 673.54 S 4579.75 g 1.16 4626.22 676.93 S 4613.03 ~ 0.50 4659.57 All data is in feet unless otherwise stated Coordinates from slot #28 and TVD from wellhead. Vertical section ts from N 0.88 W 0.15 on azimuth 259.64 degrees. Declination ts 0.00 degrees, Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad X,28 Prudhoe Bay,North Slope, Alaska Measured Inclin. Azimuth True Vert. R Depth Degrees Degrees Depth C 9435.00 19.40 264.40 7-/85.49 9530.00 18.70 263.30 7875.29 9623.00 16.30 262.60 7963.98 9716.00 15.60 263.00 8053.40 9810.00 14.40 259.80 8144.19 9906.00 13.80 259.80 8237.30 9999.00 13.10 259.50 8327.75 10094.00 10.30 257.40 8420.77 10187.00 7.00 255.60 8512.70 10281.00 5.40 256.30 8606.14 10375.00 3.50 251.40 8699.86 10484.00 2.60 254.90 8808.70 10565.00 2.90 251.90 8889.61 10595.00 2.90 248.20 8919.57 10688.00 2.42 243.70 9012.47 10780.00 2.40 10871.00 2.30 SURVEY LISTING Page 3 Your ref : EMS <10565 - 10871> Last revised : 15-Dec-93 E C T A N G U L A R Dogleg Vert 0 0 R D I N A T E S Deg/lOOFt Sect 679.95 S 4644.77 W 1.40 4691.33 683.27 S 4675.60 W 0.83 4722.25 686.69 S 4703.35 W 2.59 4750.17 689.89 S 4728.70 W 0.76 4775.69 693.50 S 4752.76 W 1.55 4799.99 697.65 S 4775.77 W 0.62 4823.38 701.53 S 4797.05 W 0.76 4845.01 705.35 S 4815.93 ~ 2.98 4864.27 708.57 S 4829.54 W 3.56 4878.23 711.04 S 4839.38 W 1.70 4888.36 713.00 S 4846.40 ~ 2.06 4895.62 714.71 S 4851.94 W 0.84 4901.38 TIE ON FOR EMS 715.82 S 4855.66 W 0.41 4905.24 716.34 S 4857.09 ~ 0.62 4906.73 718.09 S 4861.03 ~ 0.56 4910.93 246.10 9104.39 719.73 S 4864.54 W 0.11 4914.67 246.50 9195.31 721.23 S 4867.95 ~ 0.11 4918.30 AIl data is in feet unless otherwise stated Coordinates from slot #28 and TVD from wellhead. Vertical section is from N 0.88 W 0.15 on azimuth 259.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 4 Pad X,28 Your ref : EMS <10565 - 10871> Prudhoe Bay, North Slope, Alaska Last revised : 15-Dec-93 Comments in wellpath MD TVD Rectangular Coords. Comment 10484.00 8808.70 714.71 S 4851.94 W TIE ON FOR EMS All data is in feet unless otherwise stated Coordinates from slot #28 and TVD from wellhead. Bottom hole distance is 4921,09 on azimuth 261,57 degrees from wellhead. Vertical section is from N 0.88 W 0.15 on azimuth 259.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. CalcuLation uses the minimum curvature method. Presented by Baker Hughes INTEQ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. -USA Date: 14 December 1993 RE: Transmittal of Data ECC #: 6103.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP X-28 (11-07-10-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: Prints/Films: Sent by U.S. MAIL 0~ DIFL LDWG TAPE+LIST Run # 1 ~ ~ ~OO~ ~/O~OO DIFL/GR FINAL BL BHC/AC/GR FINAL BL SSTVD FINAL BL DIFL/GR FINAL RF BHC/AC/GR FINAL RF SSTVD FINAL RF Run # 1/ Run # Run # 1/ Run # 1 ~0[O0 ~tO~0 Run # 1 10%00-[0%0~ Run # 1%0 % O0 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Received by: Date: Anchorage, AK 99518 Attn. Rodney D. Paulson Till& Western Atlas International ATLAS WIRELINE SERVICES Subject: Re-distribution of LDWG Tapes and Date: 11 December 1993 final prints for X-28 From: R. Paulson To: Prudhoe Bay Log Distribution Recipients This LDWG jOb and final prints was recently distributed with the incorrect well name and API number. The incorrect information was: WELL NAME: AP1 NUMBER: X-28I 50-029-22394-01 The correct information is: WELL NAME: API NUMBER: X-28 50-029-22394-00 The corrected tapes and verification listings can be distinguished by the TAPE CREATION DATE: 11-DEC- 93. The corrected film and blueline logs can be distinguished by having the correct well name and API number mentioned above. Please re-load the data for this job from the corrected tapes and replace the incorrect prints with the corrected ones. I apologize for the inconvenience this may have caused. Regards, Rodney D. Paulson Manager, Anchorage Log Analysis Center 5600 B Street, Suite 201, Anchorage AK 99518, (907) 563-3233, Fax (907) 561-4028 T ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Reference: BP X-28I (11-07-10-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Date: 8 December 1993 RE: Transmittal of Data ECC #: 6103.00 Data: OH-LDWG Tapes/Diskettes: Prints/Films: Sent by U.S. MAIL ~ DIFL' LDWG TAPE+LIST ~DIFL/GR FINAL BL /BHC/AC/GR FINAL BL -SSTVD FINAL BLUELINE DIFL/GR FINAL RF BHC/AC/GR FINAL RF SSTVD FINAL RF Run # i ~ S~ 3'~ Run # 1 Run # 1 Run # 1 Run # 1 --IOtOO ~[O~OO 9~ Run # in ~o~0o-[~9oo ~15 Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: MEMORANDI.hfl TO: THRU: State (>. Alaska Alaska Oil and Gas Conservation Commission David Joh n,,~~, Chairmarf,,,~' Blair Wondzeil, P.I. Supervisorf~~ FROM: John Spauldingt~. SUBJECT: Petroleum InspeCtor DATE: 11-17-93 FILE NO: eholkqaa.doc Diverter Test Nabors 22E BPX/PBU/Well X-28 Prudhoe Oil Pool PTD 93-114 Wednesday November 17r, 1993' I traveled to BPX PBU Well C-28 to witness a diverter function test on Nabors 22E The test went Very well with no failures observed. The diverter lines were laid out to take advantage of the prevaling wind direction. Nabors 22E seems to have improved their maintenance a great deal. I spoke to Brian Buzby?Nabors toolpusher and expressed our appreciation. . Summary.: I witnessed the diverter test on Nabors 22E--no failures. Attachment; eholkqaa STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI~,...,SSION Diverter Systems Inspection Report Operation: Development Drlg Contractor NABORS Rig No. 22E PTD # Operator: , BPX Oper. Rep.' Well Name: ....... X728 ..... Rig Rep.: Location: Sec. 7 T. 10N R, 14E Merdian UMIAT ,,, Date: 11/17/93 XXX Exploratory: 93-114 RigPh.# BOB LAULE BRIAN BUZBY MISC. INSPECTIONS: Location Gen.: OK r Well Sign: YES Housekeeping:' 'OK (Gen.) Drlg. Rig: "OK ' Reserve Pit: .... N/A ' Flare Pit: N/A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES in. Vent Line(s) Size: 10 in. Vent Line(s) Length: 90 ft, Line(s) Bifurcated: .... YES' Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: NA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: , ~, 3100 , . psig 1700 psig min, 27 sec, 1 min. 50 sec, 8EA. 2200/~vG," psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK - OK Flow Monitor: OK oK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: VALVE~ VALVES 90' FRoM RIG TO END OF STRAIGHT F~UN 80' FROM "T" TO END OF ~IF~ BIFURCATED RUN IVERTER NABORS 22E WIND DIRECTION~ NORTH Non c~3mpii~nce Item' b ...... 0 Remarks: ...... R'e~3air Items Withir~ ' "'i bay (S) An;d co'nta(~t the'insPector @ 6~9'-360~ ' ' Distribution odg. - Well File c - Oper/Rep c - Database c - ~(Rt~. 7/93 c- Inspector AOGCC REP.' EHOLKQAA.XLs OPERATOR REP.' BOB LAULE ALASKA OIL AND GAS CONSERVATION COMMISSION August 13, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY.' (907) 276-7542 R. C. Maskell Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit X-28 BP Exploration Permit No. 93-114 Sur. Loc 4887'NSL, 84'WEL, Sec. 7, T10N, R14E, UM Btmhole Loc. 4144'NSL, 4937'WEL, Sec. 7, T10N, R14E, UM Dear Mr. Maskell: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment. (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S' Chairman ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) pJinled on recycled paper b y ,' .... STATE OF ALASKA ALAS, ~ OIL AND GAS CONSERVATION t.;OMMISSlON PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrilll-lllb. Type of well. Exploratory D Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenDI SerVice [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration. KBE = 67.88 feet Prudhoe Bay Field/Prudhoe 3. Address i6. Property Designation Bay Pool P. O. Box 196612. Anchora(Te. Alaska 99519-6612 ADL 28313 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(~e 2o ^^c 4887' NSL, 84' WEL, SEC. 7, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4144' NSL, 4937' WEL, SEC. 7, TION, R14E X-28 (11-7-10-14) 2S100302630-277 , At total depth 9. Approximate spud date Amount 4144' NSL, 4937' WEL, SEC. 7, TION, R14E 9/5/93 $200,000.00 i12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD a,d'rvD) property line ADL 47472-99' feet X-07-36'@ 7841'MD feet 2560 10814'MD/9133' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s,~ 20 AAC 2s.o35 Kickoff depth ~ooo' feet Maximum hole angle,~2.9~ o Maximum surlace 3330 psig At total depth (TVD) ~800'/4390 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.51I H-40 Weld 80' 30' 30' 110' 110' 11 yds Arcticset 16" 10-3/4" 45.5tt i NT-80 B TC 3429' 30' 30' 3459' 3200' 13~ 1 sx CS 111/'354 sx "G"/250 sx CS II 9-7/8" 7-5/8" 29.711 !NT95HS NSCC ~10514' 30' 30' 10544' 8863' 424 sx Class "G" 6-3/4" 5-1/2" 17tt L-80 FL4S 520' 10294' 8613' 10814' 9133' 90 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural~"-~ ~ ~ f~ ~,!/ ~'" Conductor ~ ~' '''~'~ t .... i~ ~-~: Surface Intermediate,.-../", !~} ~i .... !"i....,,r.,,~-~ Production Liner - Alaska Oil & (~.s (.",:~,',~. Perforation depth: measured , ............ ..v-, true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prograr, m-,SFl Time vs depth pict [] Refraction analysis i-I Seabed reportE3 20 AAC 25.050 requirementsg 21. l hereby ced_,~at the foreg, i~g is true?and correct to the best of my knowledge .,./ · . . ~' ,,,,,; .~ !' S,gned r'/;.."~ _~.~/~.C-~. '~..,,~.~'_.~.~__~.-- Title Orillin9 Engineer Supervisor Date Commission Use Only ' Permit Number IAPI number IApp~va_l date See cover letter CS_Z,,//?Z J50.d?.z_¢7... ,2_.Z.~/~,¢,¢'I L.~- //r.~ '"",,~--'~f-- }for other requrements Conditions of ap~rova Samples required [] Yes .~ No Mud Icg required []Yes ~] No Hydrogen sulfide measures [] Yes 1~ No Directional survey required '[~ Yes [] No Other:Required working pressUreoriginalfOr BOPEsigner~[]_l~y D3M; ~.SM; I-]1 OM ; D15 M; W Johnston by order of David Approved by · Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: IX-28i Well Plan Summary I Type of Well (producer or injector): I Injector Surface Location: 1 4887 FSL 84 FEL S07 T10N R14E Target Location:1 4144 FSL 4937 FEL S07 T10N R14E Bottom Hole Location: 4144 FSL 4937 FEL S07 T10N R14E I AFENumber: 14P0387 I [Rig: I Nabors 22E Estimated Start Date: I Sept 5, 1993 I ['Operating days to complete: MD: I 10814 I iTVD: I9133 I Well Design (conventional, slimhole, etc.): I Slimhole 122 I KBE: 167.88 Formation Markers: Formation Tops MD TVD (BKB) Base Permafrost 1861 1848 Ugnu 5018 4343 Seabee 7442 6118 IKRU/LCU 9610 7943 Top Sa~ River 10544 8863 Top Shublik 10564 8883 Top Sad Zone 4B 10639 8958 COWC 10689 9008 HOT 10714 9033 OOWC 10759 9078 TD 10814 9133 Casing/Tubin Program: Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 30" 20" 91.5# H-40 weld 80' 30' / 30' 110' / 110' 16" 10-3/4" 45.5# NT-80LHE BTC 3429' 30' / 30' 3459' / 3200' 9-7/8" 7-5/8" 29.7# NT-95HS NSCC 10514' 30'/30' 10544' / 8863' 6-3/4" 5-1/2" 17# L-80 FL4S 520' 10294'/8613' 10814'/9133' ~.~ !!.~. :7 '~ ~'~. Well Plan Summary Logging Pros Open Hole Logs: I Cased Hole Logs: ram: DIL/GR/BHCS: optional RFT's (10 - 15 pts) USIT or CET/CBT (cement bond log); GYRO after rig released Mud Program: Special design considerations ]None Surface Mud Properties: I Density Marsh Yield 10 sec 10 rain pH Fluid .. (PPG) Viscosity Point gel gel Loss 8.5 250 40 30 60 9 <200 to to to to to to to 9.5 300 60 60 80 10 <200 Intermediate Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel [[el Loss 9.0 30 10 5 10 9.5 15 ,,, to to to to to to t° 10.0 60 15 10 20 10.0 25 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 25 8 3 7 8 6 tO tO tO tO tO tO tO 9.0 50 13 10 15 9 8 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressureS;~,.,..: Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: [1000' Maximum Hole Angle: Close Approach Well: 42.91 X-06, X-07, and X-14 are defined as cloas approach wells The above listed wells will be secured during the close approach. Well Plan Summary Page 2 CEMENT ~ OGRAM- BJ 10-3/4" SURFACE CASING Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement: Top Job: 10 3/4% 45# 38OF 75 bbls fresh water ahead of lead slurry Coldset III Volume (sacks): 1 31 1 Additives: Retarder Weight: 12.2 ppg Mix Water: 10.5 gps Yield: 1.92 cuft/sx Thickening Time: > 4 hrs @ 50°F Class G Volume (sacks): 3 5 4 Additives: 2%A-7 + lghs FP-6L Weight: 15.8 ppg Mix Water: 4.95 gps Yield: 1.15 cuft/sx Thickening Time: >3-1/2 hfs @ 50°F Coldset II Volume (sacks): 2 5 0 Additive: Retarder Weight: 14.9 ppg Mix Water: 3.89 gps Yield: 0.96 cuft/sx Cement Volume: (1) Lead slurry from TD to surface w/ 100% excess (2) Tail slurry volume 355 sx ( to cover 500' of casing shoe w/ 100% excess + 80' shoe volume) (3) Top job volume 250 sx (fixed volume) 7-5/8" INTERMEDIATE CASING Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement: 7-5/8", 29.7# 140°F 50 bbls of Arco Alpha Spacer weighted 1 ppg above current mud weight Class G Volume (sacks): 4 2 4 Class G Volume (sacks): 263 Additives: 0.3%FL-52+0.5%CD-32+0.1%A-2+1GHS FP-6L Weight: 15.8 Ppg Mix Water: - 4.85 gps Yield: 1.14 cuft/sx Thickening Time: 3.5 - 4.5 hrs Fluid Loss: 100-150 cc Free Water: 0 mi Cement Volume: (1) Lead Slurry to 500' above top of Ugnu with 30% excess (2) Tail SlurJ'y to 1000'MD above casing point with 30% excess plus 80' 7-5/8% 29.7# capacity for float joints 5-1/2" PRODUCTION LINER Casing Size: Circ. Temp.: Spacer: Cement Type: Cement Volum 5-1/2", 17# 140°F 75 bbls of Arco Alpha Spacer mixed as per BJ specificaitons weighted 1.o ppg above mud weight Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 9 0 150 ghs BA-86L+0.6% CD-32+0.2%FL-33+0.2% A-2 +0.5% Bentonite + 2ghs FP-10L 15.7 ppg Mix Water: 3.58 gps 1.17 cult / sx Thickening Time: 45 rain @ surface + 3 to 4 hrs at 1 °-~' . < 50cc Free Water: 0 mi at 45° angle ,I ~, %;:" '" /i' /i *.,¢' ¢¢' (1) Open hc!e (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and "''~/'' ,, ..:, 'r. it indicates severe washouts). (2) 250' casing lap volume (7-5/8" X 5-1/2") .... (3) 150' casing capacity volume (7-5/8") /~:i',",ii3,:-:~,::;. :~,~ (4) 80' 5-1/2", 17# capacity for float joints ~UL-09-199~ FROM GREAT LAND DIR DRILLING TO PBD ENG I NEERS P. 06 PRUOHOE BAY DRILLING u ..... i i Il 1-- .... · X-28i (P2) VERTICAL SECTION Section st' 259.6~ TVD Scale.' ~ ~nch = 1200 fee( Scs]e 't inch VIEW <KB> ~0 !20 tBO0 8400 B 3000- K B ~600 .... J 1,,1~ ~1 'gL, g J. ~;. , , .1 &IlL, II -- ~1. f~, V ~..,/ I ~;; ~: ~ o-- A ~ Dpa~n ..... : 07/09/93 ' o ...... ' .......... j Land OimectJ ] OmJl]Jng ~ ! ! NapkeP ~dentjf~cat~on ~B 8KB SECTN [NCLN T I ~) ~8 0 0 0 O. O0 . B) KOP ~'JILD 2,0/100 t000 ~000 0 0.00 % i ,.~' I ! c) START LEFT TURN i800 ,790 gg ~6.00 ... B) SURFACE CASING 2421 2368 314 O ~. __~~ --"~ .... ~ ...... ="'~'~'T~''r''~ E) END2/ioo BL~/TURN 3269 306, 795 42.g, l ~ ..... i , .., ~ .......... ~ . .2 ~ ......... / , ·,: .¢,'~ I " ~ :J I ~ I ] .... : .... ':_. c, ~ ........ ~ ....... ~ ' .. PR'U'DHO L' BAy-'-DRZLLZN6_ Narkep Identif ication MO N/S E/W A) r,8 0 4) B) KOP BUILO 2.0/100 lO00 0 0 g~ STAflT LEFT 1UflN ~800 32 106 8J SUB=ACE CASING 242t 54 329 EJ END 2/100 8LO/TURN 3269 2 808 F) XOP ~OP ~.5/100 7~3 557 3845 G) ENO CF t.5/100 DR~ 10664 741 485~ ~) TARC~I' 10664 741 4850 lJ TD 1Q8~4 74~ X-28i (PC) PLAN VIE CLOSURE ..... : 4906 feet at Azimuth 261.32 DECLINATIO~f.' 30.000 E SCALE ' t inch = BOO feet DRA~N ' 07/09/93 1200 t500 1800 · ! i ! C,-. = ~'-'<' i ' ' .... ~ .... i , I :"" l,. ':'::,, ; i ~~.':., . ,,. .,, . .... .. - -~-..S -'. I .___~__ t .'_. . ,", .'~, -.--, I .... ' ' -- I , 5~0~ 4800 4500 ~' 4~00 390D 3600 3~0 3000 270~ 2400 2100 1800 1500 1208 900 600 300 0 300 <- NEST ' EAST -> £ ITl '--I F- Z ITl ITl JUL-09-1995 10:32 FROM GREAT LAND DIR DRILLING TO PBD ENGINEERS P,02 Great Land Directional Drilling, Inc. Client.: Field..: Pad .... : Well...: Collision Avoidance Analysis PRUDMOE BAY DRILLING NSLOPE X-Pad X28IP Method..: Date .... WellHd X: WellHd Y: Normal Plane 07/09/93 665809.29 5939734.15 Comment: X-28i (P2) Wells with minimum separation greater than 500 ft not reported. Ail depths are relative to the planned well. Existing Well X02G X03G X04G X05G X06G X07G X08G X10G XllG Xi2G X13G X14G Band Occurs at Closest Depths Point BKD MD 477 367 119 119 257 518 5i8 146 20 20 36 344 344 35 1595 1599 9i 1919 1936 148 2471 2539 142 2689 2795 177 2837 2976 169 2986 3169 84 6~08 7841 .... 100' .... ====25'- .... Warning~Band Serious-Band Enter Leave Enter Leave MD MD MD MD 19 1577 21 1957 i814 2079 7547 8106 ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE E2 thru 8] (3) Admi n (4) Cas9 (5) BOPE 2 3 4. 5. 6. 7. 8. 13] ~/~ 10. [10 & 13] 12. · 14. [1~ thru 22] 15. [23 thru 2 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES . Is permit fee attached Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... / Is sufficient undodicated acreage available in this pool ............. ~ ~_ Is well to be deviated & is wellbore plat included ................... Is operator the only affected party ............... Can permit be approved before 15-day wait Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. ~__~ Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached ..... Does BOPE have sufficient pressure rating -- test to ~--~<~ psig ..... ~-' Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease & Well NO REMARKS (6) Other /~_~ [29 thrL~ -3'1 ] (7) Contact (8) Addl [32] geology: engineering: DWJ~ MTM - RAD~C]~_~I R P~?~'~. BEW-~ JDHd~ TAB~-- rev 6/93 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... / / Additional requirements ............................................. //u~ Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE MERIDIAN' UM~ SM WELL TYPE' Exp/~.~y~ X~ Red r il 1 Inj.~ Rev 0 ~ZZ ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL- · ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6103.00 R. ECK D. BOYER REMARKS: X - 28 (11-7-10-14) 500292239400 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES il-DEC-93 RUN 2 RUN 3 4887 84 DIFL/AC/GR CIRCULATION STOPPED @ 03: 30, 02-DEC-93. 7.625 10557.0 6.750 10905.0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7 i0N 14E 68.00 68.00 39.00 FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data° DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 10549.0 10852.0 10549.0 10870.0 10549.0 10899.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 10549.0 10549.0 10557.0 10560.0 10565.0 10574.0 10574.5 10577.0 10577.5 10578.0 10577.5 10583.0 10583.0 10583.5 10585.0 10585.0 10585.5 10590.5 10590.5 10593.0 10597.5 10598.0 10599.0 10600.5 10601.0 10604.0 10606.0 10611.0 10621.5 10621.5 10624.0 10624.0 10624.5 10625.5 10628.0 10630.0 10632.5 10632.5 10637.5 10639.5 10639.5 10641.0 10642.0 10644.0 10643.5 10650.5 10652.5 10657.0 10659.5 10668.0 10667.5 10669.5 10669.5 10672.0 10674.0 all runs merged; EQUIVALENT UNSHIFTED DEPTH LL8 ILM 10549.0 10549.0 10556.0 10560.0 10564.5 10573.5 10573.5 10577.0 10578.5 10582.0 10584.0 10586.0 10585.5 10589.5 10589.5 10592.5 10596.0 10597.5 10598.5 10601.0 10604.5 10606.0 10611.0 10627.5 10627.0 10630.0 10637.0 10638.5 10641.0 10640.0 10642.5 10644.0 10650.5 10652.5 10652.0 10659.0 SP 10549.0 10577.0 10652.5 10657.0 10659.0 10672.0 10671.0 10674.0 10672.0 no case 10677.5 10681.5 10683.5 10685.0 10707.5 10708.0 10710.0 10719.0 10732.5 10735.0 10739.5 10742.0 10761.5 10770.0 10781.0 10782.5 10786.5 10795.0 10805.5 10806.0 10808.0 10809.5 10810.0 10816.0 10816.5 10831.0 10841.0 10844.0 10860.0 10860.5 10872.5 10881.5 10925.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL $ REMARKS: 10677.5 10677.0 10677.5 10681.0 10682.0 10683.5 10683.5 10684.5 10708.0 10707.5 10708.0 10709.0 10718.5 10719.0 10719.0 10732.0 10735.5 10735.5 10734.5 10735.0 10739.5 10742.5 10761.5 10761.5 10769.5 10780.5 10781.0 10780.5 10782.0 10780.5 10785.5 10786.0 10795.0 10795.0 10806.0 10806.0 10807.0 10806.5 10809.0 10809.0 10815.5 10830.5 10840.5 10859.5 10859.0 10871.0 10881.0 10925.0 10925.0 10925.0 10810.0 10816.0 10843.5 10925.0 RUN NO. PASS NO. MERGE TOP 1 4 10549.0 1 4 10549.0 1 4 10549.0 OPEN HOLE MAIN PASS. TEND, TENS, & MTEM WERE SHIFTED WITH LLS. ILD WAS SHIFTED WITH ILM. MERGE BASE 10852.0 10870.0 10899.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT /??MATCH4. OUT $ CN : BP EXPLORATION WN : X - 28 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL8 DIL 68 1 OHMM 4 6 ILM DIL 68 1 OHMM 4 7 ILD DIL 68 1 OHMM 4 8 SP DIL 68 1 MV 4 9 MTEM DIL 68 1 DEGF 4 4 4 4 4 36 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 50 746 76 1 50 746 76 1 50 746 76 1 50 746 76 1 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 31 Tape File Start Depth = 10925.000000 Tape File End Depth = 10549.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7531 datums Tape Subfile: 2 189 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: 0.5000 START DEPTH 10053.0 STOP DEPTH 10549.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE MAIN PASS. CN : BP EXPLORATION WN : X - 28 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 TEND GR 68 1 LB 4 3 TENS GR 68 1 LB 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 17 Tape File Start Depth = 10549.000000 Tape File End Depth = 10035.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4117 datums Tape Subfile: 3 44 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10485.0 AC DIFL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 10503.0 10530.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION CHT MIS TEMP PCM GR AC DIFL $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: STOP DEPTH 10868.0 10886.0 10915.0 02-DEC-93 FSYS REV. J001 VER. 1.1 330 02-DEC-93 1157 02-DEC-93 10905.0 10903.0 10100.0 10899.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 6.750 10557.0 10549.0 LSND 8.80 42.0 11.0 7.2 188.0 2.540 0.950 3.240 70.0 188.0 63.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS (open hole). $ CN : BP EXPLORATION WN : X - 28 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.000 0.0 1.850 64.0 0.O0O 0.0 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 TEN AC 68 1 LB 4 11 SPD AC 68 1 F/MN 4 12 RFOC DIFL 68 1 OHMM 4 13 RILM DIFL 68 1 OHMM 4 14 RILD DIFL 68 1 OHMM 4 15 CILD DIFL 68 1 MMHO 4 16 VILD DIFL 68 1 MV 4 17 VILM DIFL 68 1 MV 4 18 SP DIFL 68 1 MV 4 19 TEMP DIFL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 155 Tape File Start Depth = 10925.000000 Tape File End Depth = 10461.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44672 datums Tape Subfile: 4 231 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 10487.0 AC 10504.0 DIFL 10531.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10868.0 10886.0 10915.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: 02-DEC-93 FSYS REV. J001 VER. 1.1 330 02-DEC-93 1136 02-DEC-93 10905.0 10903.0 10100.0 10899.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 6.750 10557.0 10549.0 LSND 8.80 42.0 11.0 7.2 188.0 2.540 0.950 3.240 0.000 1.850 70.0 188.0 63.0 0.0 64.0 MUD CAKE AT BHT: 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : X - 28 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 TEN AC 68 1 LB 4 11 SPD AC 68 1 F/MN 4 12 RFOC DIFL 68 1 OHMM 4 13 RILM DIFL 68 1 OHMM 4 14 RILD DIFL 68 1 OHMM 4 15 CILD DIFL 68 1 MMHO 4 16 VILD DIFL 68 1 MV 4 17 VILM DIFL 68 1 MV 4 18 SP DIFL 68 1 MV 4 19 TEMP DIFL 68 1 DEGF 4 4 4 4 4 4 4 04 522 4 53 419 4 40 467 76 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 27 515 24 6 06 213 78 0 04 903 06 0 34 704 23 6 04 522 10 6 10 6 67 0 34 0 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 153 Tape File Start Depth Tape File End Depth = 10925.000000 = 10469.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40618 datums Tape Subfile: 5 227 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10053.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ STOP DEPTH 10586.0 CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION 02-DEC-93 FSYS REV. J001 VER. 1.1 330 02-DEC-93 1221 02-DEC-93 10905.0 10903.0 10100.0 10899.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 10557.0 10549.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: LSND 8.80 42.0 11.0 7.2 188.0 2.540 0.950 3.240 0.000 1.850 0.000 70.0 188.0 63.0 0.0 64.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): REMARKS: CASED HOLE MAIN PASS. $ CN : BP EXPLORATION WN : X - 28 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR GR 68 2 CHT GR 68 3 TTEN GR 68 4 TEN GR 68 5 SPD GR '68 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GAPI 4 1 LB 4 1 LB 4 1 LB 4 1 F/MN 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 4 10 579 41 1 4 76 115 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 58 Tape File Start Depth = 10643.000000 Tape File End Depth = 10035.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59271 datums Tape Subfile: 6 127 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS 93/12/ 6 01 **** REEL TRAILER **** 93/12/11 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 11 DEC 93 ll:50a Elapsed execution time = 19.28 seconds. SYSTEM RETURN CODE = 0